Nevada Power (NVP) 10-K 27 Feb 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Feb. 17, 2017	Jun. 30, 2016
Document Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Entity Registrant Name	BERKSHIRE HATHAWAY ENERGY CO
Entity Central Index Key	1,081,316
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		77,356,144
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 0
PacifiCorp [Member]
Document Information [Line Items]
Entity Registrant Name	PACIFICORP /OR/
Entity Central Index Key	75,594
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		357,060,915
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			0
MidAmerican Funding, LLC and Subsidiaries [Domain]
Document Information [Line Items]
Entity Registrant Name	MIDAMERICAN FUNDING, LLC
Entity Central Index Key	1,098,296
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	Yes
Entity Current Reporting Status	No
Entity Public Float			0
MidAmerican Energy Company and Subsidiaries [Member]
Document Information [Line Items]
Entity Registrant Name	MIDAMERICAN ENERGY COMPANY
Entity Central Index Key	928,576
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		70,980,203
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			0
Nevada Power Company [Member]
Document Information [Line Items]
Entity Registrant Name	NEVADA POWER COMPANY
Entity Central Index Key	71,180
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		1,000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			0
Sierra Pacific Power Company [Member]
Document Information [Line Items]
Entity Registrant Name	SIERRA PACIFIC POWER COMPANY
Entity Central Index Key	90,144
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		1,000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 0

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents		$ 721	$ 1,108
Trade receivables, net		1,751	1,785
Income taxes receivable		0	319
Inventories
Fuel		402	353
Inventories		925	882
Mortgage loans held for sale		359	335
Other current assets		917	814
Total current assets		4,673	5,243
Regulatory assets		150	130
Property, plant and equipment, net		62,509	60,769
Goodwill		9,010	9,076
Regulatory assets		4,307	4,155
Investments and restricted cash and investments		3,945	3,367
Other assets		996	1,008
Total assets		85,440	83,618
Current liabilities:
Accounts payable		1,317	1,564
Accrued interest		454	469
Accrued property, income and other taxes		389	372
Accrued employee expenses		261	264
Regulatory liabilities		187	402
Short-term debt	[1]	1,869	974
Current portion of long-term debt		1,006	1,148
Other current liabilities		830	896
Total current liabilities		6,313	6,089
Regulatory liabilities		2,933	2,631
BHE senior debt		7,418	7,814
BHE junior subordinated debentures		944	2,944
Subsidiary debt		26,748	26,066
Deferred income taxes		13,879	12,685
Other long-term liabilities		2,742	2,854
Total liabilities		60,977	61,083
Asset Retirement Obligations, Noncurrent		856	829
Commitments and contingencies
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		6,390	6,403
Retained earnings		19,448	16,906
Accumulated other comprehensive loss, net		(1,511)	(908)
Total shareholders' equity		24,327	22,401
Noncontrolling interests		136	134
Total equity		24,463	22,535
Total liabilities and equity		85,440	83,618
Sierra Pacific Power Company [Member]
Current assets:
Cash and cash equivalents		55	106
Trade receivables, net		117	124
Inventories
Fuel		9	5
Inventories		45	39
Other current assets		13	13
Total current assets		255	282
Regulatory assets		25	0
Public Utilities, Property, Plant and Equipment, Net		2,822	2,766
Regulatory assets		410	432
Other assets		6	7
Total assets		3,493	3,487
Current liabilities:
Accounts payable		146	127
Accrued interest		14	15
Accrued property, income and other taxes		10	13
Regulatory liabilities		69	78
Long-term Debt and Capital and Financial Lease Obligations, Current		1	453
Customer Deposits, Current		16	17
Other current liabilities		12	11
Total current liabilities		268	714
Regulatory liabilities		221	230
Deferred income taxes		617	570
Other long-term liabilities		127	148
Total liabilities		2,385	2,411
Asset Retirement Obligations, Noncurrent		10	10
Long-term Debt and Capital and Financial Lease Obligations		1,152	749
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		1,111	1,111
Retained earnings		(2)	(35)
Accumulated other comprehensive loss, net		(1)	0
Total shareholders' equity		1,108	1,076
Total liabilities and equity		3,493	3,487
PacifiCorp [Member]
Current assets:
Cash and cash equivalents		17	12
Trade receivables, net		728	740
Income taxes receivable		17	17
Inventories
Materials and supplies		228	233
Fuel		215	192
Other current assets		96	81
Total current assets		1,354	1,377
Regulatory assets		53	102
Public Utilities, Property, Plant and Equipment, Net		19,162	19,026
Regulatory assets		1,490	1,583
Other assets		388	381
Total assets		22,394	22,367
Current liabilities:
Accounts payable		408	473
Accrued interest		115	115
Accrued property, income and other taxes		63	62
Accrued employee expenses		67	70
Regulatory liabilities		54	34
Short-term debt		270	20
Current portion of long-term debt and capital lease obligations		58	68
Other current liabilities		164	229
Total current liabilities		1,199	1,071
Regulatory liabilities		978	938
Deferred income taxes		4,880	4,750
Other long-term liabilities		926	1,027
Total liabilities		15,004	14,864
Asset Retirement Obligations, Noncurrent		194	189
Commitments and contingencies
Long-term debt and capital lease obligations		7,021	7,078
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		4,479	4,479
Retained earnings		2,921	3,033
Accumulated other comprehensive loss, net		(12)	(11)
Total shareholders' equity		7,390	7,503
Preferred stock		2	2
Total liabilities and equity		22,394	22,367
MidAmerican Energy Company [Member]
Current assets:
Cash and cash equivalents		14	103
Receivables, Net, Current		285	342
Income taxes receivable		9	104
Inventories
Inventories		264	238
Other current assets		35	58
Total current assets		607	845
Public Utilities, Property, Plant and Equipment, Net		12,821	11,723
Regulatory assets		1,161	1,044
Investments and restricted cash and investments		653	634
Other assets		217	139
Total assets		15,459	14,385
Current liabilities:
Accounts payable		303	426
Accrued interest		45	46
Accrued property, income and other taxes		137	125
Short-term debt		99	0
Current portion of long-term debt and capital lease obligations		250	34
Other current liabilities		159	166
Total current liabilities		993	797
Regulatory liabilities		883	831
Deferred income taxes		3,572	3,061
Other long-term liabilities		290	266
Total liabilities		10,299	9,680
Asset Retirement Obligations, Noncurrent		510	488
Commitments and contingencies
Long-term debt and capital lease obligations		4,051	4,237
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		561	561
Retained earnings		4,599	4,174
Accumulated other comprehensive loss, net		0	(30)
Total shareholders' equity		5,160	4,705
Total liabilities and equity		15,459	14,385
MidAmerican Funding, LLC and Subsidiaries [Domain]
Current assets:
Cash and cash equivalents		15	103
Receivables, Net, Current		287	346
Income taxes receivable		9	104
Inventories
Inventories		264	238
Other current assets		35	58
Total current assets		610	849
Property, plant and equipment, net		12,835	11,737
Goodwill		1,270	1,270
Regulatory assets		1,161	1,044
Investments and restricted cash and investments		655	636
Other assets		216	138
Total assets		16,747	15,674
Current liabilities:
Accounts payable		302	427
Accrued interest		52	53
Accrued property, income and other taxes		138	125
Notes Payable, Related Parties, Current		31	139
Short-term debt		99	0
Current portion of long-term debt and capital lease obligations		250	34
Other current liabilities		160	166
Total current liabilities		1,032	944
Regulatory liabilities		883	831
Deferred income taxes		3,568	3,056
Other long-term liabilities		291	267
Total liabilities		10,661	10,149
Asset Retirement Obligations, Noncurrent		510	488
Commitments and contingencies
Long-term debt and capital lease obligations		4,377	4,563
Shareholders' equity:
Additional paid-in capital		1,679	1,679
Retained earnings		4,407	3,876
Accumulated other comprehensive loss, net		0	(30)
Total shareholders' equity		6,086	5,525
Total liabilities and equity		16,747	15,674
Nevada Power Company [Member]
Current assets:
Cash and cash equivalents		279	536
Trade receivables, net		243	265
Inventories
Fuel		13	22
Inventories		73	80
Other current assets		38	46
Total current assets		653	927
Regulatory assets		20	0
Public Utilities, Property, Plant and Equipment, Net		6,997	6,996
Regulatory assets		1,000	1,057
Other assets		39	37
Total assets		8,689	9,017
Current liabilities:
Accounts payable		187	214
Accrued interest		50	54
Accrued property, income and other taxes		93	30
Regulatory liabilities		37	173
Long-term Debt and Capital and Financial Lease Obligations, Current		17	225
Customer Deposits, Current		78	58
Other current liabilities		39	28
Total current liabilities		501	782
Regulatory liabilities		416	304
Deferred income taxes		1,474	1,405
Other long-term liabilities		277	303
Total liabilities		5,717	5,854
Asset Retirement Obligations, Noncurrent		63	72
Long-term Debt and Capital and Financial Lease Obligations		3,049	3,060
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		2,308	2,308
Retained earnings		667	858
Accumulated other comprehensive loss, net		(3)	(3)
Total shareholders' equity		2,972	3,163
Total liabilities and equity		$ 8,689	$ 9,017
[1]	The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2016	Dec. 31, 2015
Shareholders' equity:
Common stock, par value	$ 0	$ 0
Common stock, shares authorized	115,000,000	115,000,000
Common stock, shares issued	77,000,000	77,000,000
Common stock, shares outstanding	77,000,000	77,000,000
PacifiCorp [Member]
Shareholders' equity:
Common stock, par value	$ 0	$ 0
Common stock, shares authorized	750,000,000	750,000,000
Common stock, shares issued	357,000,000	357,000,000
Common stock, shares outstanding	357,000,000	357,000,000
Nevada Power Company [Member]
Shareholders' equity:
Common Stock, Par or Stated Value Per Share	$ 1	$ 1
Common stock, shares authorized	1,000	1,000
Common stock, shares issued	1,000	1,000
Common stock, shares outstanding	1,000	1,000
Sierra Pacific Power Company [Member]
Shareholders' equity:
Common Stock, Par or Stated Value Per Share	$ 3.75	$ 3.75
Common stock, shares authorized	20,000,000	20,000,000
Common stock, shares issued	1,000	1,000
Common stock, shares outstanding	1,000	1,000
Common Stock [Member]
Shareholders' equity:
Common stock, shares outstanding	77,000,000	77,000,000
Common Stock [Member] | MidAmerican Energy Company [Member]
Shareholders' equity:
Common Stock, Par or Stated Value Per Share	$ 0	$ 0
Common stock, shares authorized	350,000,000	350,000,000
Common stock, shares issued	70,980,203	70,980,203
Common stock, shares outstanding	70,980,203	70,980,203
Common Stock [Member] | Nevada Power Company [Member]
Shareholders' equity:
Common stock, shares outstanding	1,000	1,000
Common Stock [Member] | Sierra Pacific Power Company [Member]
Shareholders' equity:
Common stock, shares outstanding	1,000	1,000

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating revenue:
Energy	$ 14,621	$ 15,354	$ 15,182
Real estate	2,801	2,526	2,144
Total operating revenue	17,422	17,880	17,326
Energy:
Cost of sales	4,315	5,079	5,732
Operating expense	3,707	3,732	3,501
Depreciation and amortization	2,560	2,399	2,028
Real estate	2,589	2,342	2,019
Total operating costs and expenses	13,171	13,552	13,280
Operating income	4,251	4,328	4,046
Other income (expense):
Interest expense	(1,854)	(1,904)	(1,711)
Capitalized interest and allowance for borrowed funds	139	74	89
Allowance for equity funds	158	91	98
Other Interest and Dividend Income	120	107	38
Other, net	36	39	42
Total other income (expense)	(1,401)	(1,593)	(1,444)
Income before income tax expense and equity income	2,850	2,735	2,602
Income tax expense	403	450	589
Equity income (loss)	123	115	109
Net income	2,570	2,400	2,122
Net income attributable to noncontrolling interests	28	30	27
Net income (loss) attributable to parent	2,542	2,370	2,095
PacifiCorp [Member]
Operating revenue:
Electric Domestic Regulated Revenue	5,201	5,232	5,252
Energy:
Energy costs	1,751	1,868	1,997
Operations and maintenance	1,064	1,082	1,057
Utilities Operating Expense, Depreciation and Amortization	770	757	726
Taxes, other than income taxes	190	185	172
Total operating costs and expenses	3,775	3,892	3,952
Operating income	1,426	1,340	1,300
Other income (expense):
Interest expense	(380)	(379)	(379)
Capitalized interest and allowance for borrowed funds	15	18	25
Allowance for equity funds	27	33	51
Other, net	15	11	10
Total other income (expense)	(323)	(317)	(293)
Income before income tax expense and equity income	1,103	1,023	1,007
Income tax expense	340	328	309
Net income (loss) attributable to parent	763	695	698
MidAmerican Energy Company [Member]
Operating revenue:
Electric Domestic Regulated Revenue	1,985	1,837	1,817
Gas Domestic Regulated Revenue and Other	640	665	1,005
Total operating revenue	2,625	2,502	2,822
Energy:
Energy costs	409	433	532
Cost of natural gas purchases and other	367	398	720
Operations and maintenance	693	705	717
Utilities Operating Expense, Depreciation and Amortization	479	407	351
Taxes, other than income taxes	112	110	108
Total operating costs and expenses	2,060	2,053	2,428
Operating income	565	449	394
Other income (expense):
Interest expense	(196)	(183)	(174)
Capitalized interest and allowance for borrowed funds	8	8	16
Allowance for equity funds	19	20	39
Other, net	14	5	10
Total other income (expense)	(155)	(150)	(109)
Income before income tax expense and equity income	410	299	285
Income tax expense	(132)	(147)	(116)
Net income	542	446	401
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	0	22	28
Discontinued Operation, Tax Effect of Discontinued Operation	0	6	12
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	0	16	16
Net income (loss) attributable to parent	542	462	417
MidAmerican Funding, LLC and Subsidiaries [Domain]
Operating revenue:
Electric Domestic Regulated Revenue	1,985	1,837	1,817
Gas Domestic Regulated Revenue and Other	646	678	1,027
Total operating revenue	2,631	2,515	2,844
Energy:
Energy costs	409	433	532
Cost of natural gas purchases and other	371	407	738
Operations and maintenance	694	707	720
Utilities Operating Expense, Depreciation and Amortization	479	407	351
Taxes, other than income taxes	112	110	108
Total operating costs and expenses	2,065	2,064	2,449
Operating income	566	451	395
Other income (expense):
Interest expense	(219)	(206)	(197)
Capitalized interest and allowance for borrowed funds	8	8	16
Allowance for equity funds	19	20	39
Other, net	19	19	18
Total other income (expense)	(173)	(159)	(124)
Income before income tax expense and equity income	393	292	271
Income tax expense	(139)	(150)	(122)
Net income	532	442	393
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	0	22	28
Discontinued Operation, Tax Effect of Discontinued Operation	0	6	12
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	0	16	16
Net income (loss) attributable to parent	532	458	409
Nevada Power Company [Member]
Operating revenue:
Total operating revenue	2,083	2,402	2,337
Energy:
Cost of sales	768	1,084	1,076
Operations and maintenance	394	372	413
Utilities Operating Expense, Depreciation and Amortization	303	297	274
Taxes, other than income taxes	38	36	33
Total operating costs and expenses	1,503	1,789	1,796
Operating income	580	613	541
Other income (expense):
Interest expense	(185)	(190)	(208)
Capitalized interest and allowance for borrowed funds	4	3	1
Allowance for equity funds	2	4	1
Other, net	24	20	22
Total other income (expense)	(155)	(163)	(184)
Income before income tax expense and equity income	425	450	357
Income tax expense	146	162	130
Net income (loss) attributable to parent	279	288	227
Sierra Pacific Power Company [Member]
Operating revenue:
Electric Domestic Regulated Revenue	702	810	779
Gas Domestic Regulated Revenue	110	137	125
Total operating revenue	812	947	904
Energy:
Cost of sales	265	374	361
Cost of Purchased Oil and Gas	55	84	76
Operations and maintenance	170	167	162
Utilities Operating Expense, Depreciation and Amortization	118	113	105
Taxes, other than income taxes	24	25	22
Total operating costs and expenses	632	763	726
Operating income	180	184	178
Other income (expense):
Interest expense	(54)	(61)	(61)
Capitalized interest and allowance for borrowed funds	4	2	2
Allowance for equity funds	(1)	2	3
Other, net	4	3	12
Total other income (expense)	(47)	(54)	(44)
Income before income tax expense and equity income	133	130	134
Income tax expense	49	47	47
Net income (loss) attributable to parent	$ 84	$ 83	$ 87

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net income	$ 2,570	$ 2,400	$ 2,122
Net income (loss) attributable to parent	2,542	2,370	2,095
Other comprehensive loss, net of tax:
Unrecognized amounts on retirement benefits, net of tax	(9)	52	69
Foreign currency translation adjustment	(583)	(680)	(314)
Unrealized (losses) gains on cash flow hedges, net of tax	19	(11)	(18)
Total other comprehensive loss, net of tax	(603)	(414)	(397)
Comprehensive income	1,967	1,986	1,725
Comprehensive income attributable to noncontrolling interests	28	30	27
Comprehensive income attributable to shareholders	1,939	1,956	1,698
Nevada Power Company [Member]
Net income (loss) attributable to parent	279	288	227
Parent Company [Member]
Net income	2,545	2,373	2,097
Net income (loss) attributable to parent	2,542	2,370	2,095
Other comprehensive loss, net of tax:
Total other comprehensive loss, net of tax	(603)	(414)	(397)
Comprehensive income	1,942	1,959	1,700
Comprehensive income attributable to noncontrolling interests	3	3	2
Comprehensive income attributable to shareholders	1,939	1,956	1,698
PacifiCorp [Member]
Net income (loss) attributable to parent	763	695	698
Other comprehensive loss, net of tax:
Unrecognized amounts on retirement benefits, net of tax	(1)	2	(4)
Total other comprehensive loss, net of tax	(1)	2	(4)
Comprehensive income attributable to shareholders	762	697	694
MidAmerican Energy Company [Member]
Net income (loss) attributable to parent	542	462	417
Other comprehensive loss, net of tax:
Unrealized gains (losses) on available-for-sale securities, net of tax	3	0	1
Unrealized (losses) gains on cash flow hedges, net of tax	0	(7)	(13)
Total other comprehensive loss, net of tax	3	(7)	(12)
Comprehensive income attributable to shareholders	545	455	405
MidAmerican Funding, LLC and Subsidiaries [Domain]
Net income (loss) attributable to parent	532	458	409
Other comprehensive loss, net of tax:
Unrealized gains (losses) on available-for-sale securities, net of tax	3	0	1
Unrealized (losses) gains on cash flow hedges, net of tax	0	(7)	(13)
Total other comprehensive loss, net of tax	3	(7)	(12)
Comprehensive income attributable to shareholders	$ 535	$ 451	$ 397

Consolidated Statements of Com6

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income tax effect - unrecognized amounts on retirement benefits	$ 11	$ 17	$ 19
Income tax effect - unrealized gains (losses) on available-for-sale securities	(19)	129	(84)
Income tax effect - unrealized (losses) gains on cash flow hedges	13	(7)	(13)
MidAmerican Funding, LLC and Subsidiaries [Domain]
Income tax effect - unrealized gains (losses) on available-for-sale securities	1	0	1
Income tax effect - unrealized (losses) gains on cash flow hedges	0	(4)	(10)
MidAmerican Energy Company [Member]
Income tax effect - unrealized gains (losses) on available-for-sale securities	1	0	1
Income tax effect - unrealized (losses) gains on cash flow hedges	0	(4)	(10)
PacifiCorp [Member]
Income tax effect - unrecognized amounts on retirement benefits	$ (1)	$ 3	$ (1)

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]	PacifiCorp [Member]	PacifiCorp [Member]Preferred Stock [Member]	PacifiCorp [Member]Common Stock [Member]	PacifiCorp [Member]Additional Paid-in Capital [Member]	PacifiCorp [Member]Retained Earnings [Member]	PacifiCorp [Member]Accumulated Other Comprehensive Income (Loss) [Member]	MidAmerican Energy Company [Member]	MidAmerican Energy Company [Member]Common Stock [Member]	MidAmerican Energy Company [Member]Retained Earnings [Member]	MidAmerican Energy Company [Member]Accumulated Other Comprehensive Income (Loss) [Member]	MidAmerican Funding, LLC and Subsidiaries [Domain]	MidAmerican Funding, LLC and Subsidiaries [Domain]Additional Paid-in Capital [Member]	MidAmerican Funding, LLC and Subsidiaries [Domain]Retained Earnings [Member]	MidAmerican Funding, LLC and Subsidiaries [Domain]Accumulated Other Comprehensive Income (Loss) [Member]	Sierra Pacific Power Company [Member]	Sierra Pacific Power Company [Member]Common Stock [Member]	Sierra Pacific Power Company [Member]Additional Paid-in Capital [Member]	Sierra Pacific Power Company [Member]Retained Earnings [Member]	Sierra Pacific Power Company [Member]Accumulated Other Comprehensive Income (Loss) [Member]	Nevada Power Company [Member]	Nevada Power Company [Member]Common Stock [Member]	Nevada Power Company [Member]Additional Paid-in Capital [Member]	Nevada Power Company [Member]Retained Earnings [Member]	Nevada Power Company [Member]Accumulated Other Comprehensive Income (Loss) [Member]
Balance (shares) at Dec. 31, 2013		77,000,000																				1,000					1,000
Balance at Dec. 31, 2013	$ 18,816	$ 0	$ 6,390	$ 12,418	$ (97)	$ 105
Balance at Dec. 31, 2013							$ 7,787	$ 2	$ 0	$ 4,479	$ 3,315	$ (9)	$ 3,845	$ 561	$ 3,295	$ (11)	$ 4,677	$ 1,679	$ 3,009	$ (11)	$ 1,016	$ 0	$ 1,111	$ (93)	$ (2)	$ 2,890	$ 0	$ 2,308	$ 586	$ (4)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,112	0	0	2,095	0	17
Net income	2,122
Net income (loss) attributable to parent	2,095						698		0	0	698	0	417		417		409		409		87			87		227			227
Other comprehensive income (loss)	(397)	0	0	0	(397)	0	(4)		0	0	0	(4)	(12)			(12)	(12)			(12)
Dividend, noncash, transfer of operations													0				0
Distributions	(22)	0	0	0	0	(22)
Common stock dividends declared							(725)		0	0	(725)	0									(105)			(105)		(230)			(230)
Other equity transactions	64	$ 0	33	0	0	31											(1)		(1)							1				1
Balance (shares) at Dec. 31, 2014		77,000,000																				1,000					1,000
Balance at Dec. 31, 2014	20,573	$ 0	6,423	14,513	(494)	131
Balance at Dec. 31, 2014							7,756	2	0	4,479	3,288	(13)	4,250	$ 561	3,712	(23)	5,073	1,679	3,417	(23)	998	$ 0	1,111	(111)	(2)	2,888	$ 0	2,308	583	(3)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,388	0	0	2,370	0	18
Net income	2,400
Net income (loss) attributable to parent	2,370						695		0	0	695	0	462		462		458		458		83			83		288			288
Other comprehensive income (loss)	(414)	0	0	0	(414)	0	2		0	0	0	2	(7)			(7)	(7)			(7)
Dividend, noncash, transfer of operations													0				0
Distributions	(21)	0	0	0	0	(21)
Common stock dividends declared							$ (950)		0	0	(950)	0									(7)			(7)		$ (13)			(13)
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results	67			56		11
Common stock, value, repurchased	(36)		(3)	(33)
Other equity transactions	$ (22)	$ 0	(17)	0	0	(5)											(1)		(1)		$ 2				2
Balance (shares) at Dec. 31, 2015	77,000,000	77,000,000					357,000,000							70,980,203							1,000	1,000				1,000	1,000
Balance at Dec. 31, 2015	$ 22,535	$ 0	6,403	16,906	(908)	134
Balance at Dec. 31, 2015	22,401						$ 7,503	2	0	4,479	3,033	(11)	4,705	$ 561	4,174	(30)	5,525	1,679	3,876	(30)	$ 1,076	$ 0	1,111	(35)	0	$ 3,163	$ 0	2,308	858	(3)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,556	0	0	2,542	0	14
Net income	2,570
Net income (loss) attributable to parent	2,542						763		0	0	763	0	542		542		532		532		84			84		279			279
Other comprehensive income (loss)	(603)	0	0	0	(603)	0	(1)		0	0	0	(1)	3			3	3			3
Stockholders' equity transfer to affiliate																	27			27
Dividend, noncash, transfer of operations													(90)		(117)	(27)	(90)
Distributions	(20)	0	0	0	0	(20)
Common stock dividends declared							$ (875)		0	0	(875)	0									(51)			(51)		(469)			(469)
Other equity transactions	$ (5)	$ 0	(13)	0	0	8											(1)		(1)		$ (1)				(1)	$ (1)			(1)
Balance (shares) at Dec. 31, 2016	77,000,000	77,000,000					357,000,000							70,980,203							1,000	1,000				1,000	1,000
Balance at Dec. 31, 2016	$ 24,463	$ 0	$ 6,390	$ 19,448	$ (1,511)	$ 136
Balance at Dec. 31, 2016	$ 24,327						$ 7,390	$ 2	$ 0	$ 4,479	$ 2,921	$ (12)	$ 5,160	$ 561	$ 4,599	$ 0	$ 6,086	$ 1,679	$ 4,407	$ 0	$ 1,108	$ 0	$ 1,111	$ (2)	$ (1)	$ 2,972	$ 0	$ 2,308	$ 667	$ (3)

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash flows from operating activities:
Net income	$ 2,570	$ 2,400	$ 2,122
Net income (loss) attributable to parent	2,542	2,370	2,095
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	2,591	2,428	2,057
Allowance for equity funds	(158)	(91)	(98)
Equity (income) loss, net of distributions	(123)	(115)	(109)
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions	(67)	(38)	(79)
Changes in regulatory assets and liabilities	(34)	356	(168)
Deferred income taxes and amortization of investment tax credits	1,090	1,265	2,335
Other, net	(80)	11	147
Changes in other operating assets and liabilities, net of effects from acquisitions:
Trade receivables and other assets	(158)	(9)	(44)
Derivative collateral, net	32	(14)	(70)
Pension and other postretirement benefit plans	(79)	(11)	86
Accrued property, income and other taxes	377	877	(1,117)
Accounts payable and other liabilities	(28)	(194)	(25)
Net cash flows from operating activities	6,056	6,980	5,146
Cash flows from investing activities:
Capital expenditures	(5,090)	(5,875)	(6,555)
Acquisitions, net of cash acquired	(66)	(164)	(2,956)
(Increase) decrease in restricted cash and investments	(36)	(28)	173
Purchases of available-for-sale securities	(141)	(144)	(150)
Proceeds from sales of available-for-sale securities	191	142	118
Equity method investments	(570)	(202)	(37)
Other, net	(34)	41	(11)
Net cash flows from investing activities	(5,746)	(6,230)	(9,418)
Cash flows from financing activities:
Proceeds from BHE senior debt	0	0	1,478
Proceeds from BHE junior subordinated debentures	0	0	1,500
Repayments of BHE senior debt and junior subordinated debentures	(2,000)	(850)	(550)
Payments for Repurchase of Common Stock	0	(36)	0
Proceeds from subsidiary debt	2,327	2,479	1,257
Repayments of subsidiary debt	(1,831)	(1,354)	(971)
Net proceeds from (repayments of) short-term debt	879	(421)	1,055
Other, net	(65)	(73)	(44)
Net cash flows from financing activities	(690)	(255)	3,725
Effect of exchange rate changes	(7)	(4)	(11)
Net change in cash and cash equivalents	(387)	491	(558)
Cash and cash equivalents at beginning of period	1,108	617	1,175
Cash and cash equivalents at end of period	721	1,108	617
Parent Company [Member]
Cash flows from operating activities:
Net income	2,545	2,373	2,097
Net income (loss) attributable to parent	2,542	2,370	2,095
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	4	3	3
Equity (income) loss, net of distributions	(2,805)	(2,646)	(2,402)
Changes in other operating assets and liabilities, net of effects from acquisitions:
Net cash flows from operating activities	2,760	2,528	1,937
Cash flows from investing activities:
Investments in subsidiaries	1,080	1,506	4,937
Purchases of available-for-sale securities	(24)	(36)	(56)
Proceeds from sales of available-for-sale securities	20	47	35
Repayment of (Issuance of) Notes Receivable with Related Parties, Net	(307)	19	(55)
Other, net	(5)	(7)	(7)
Net cash flows from investing activities	(1,396)	(1,483)	(5,020)
Cash flows from financing activities:
Proceeds from BHE senior debt	0	0	1,478
Proceeds from BHE junior subordinated debentures	0	0	1,500
Proceeds from issuance of BHE common stock	0	0	0
Payments for Repurchase of Common Stock	0	(36)	0
Net proceeds from (repayments of) short-term debt	581	(142)	395
Notes payable to affiliate, net	69	4	(30)
Other, net	(4)	(1)	1
Net cash flows from financing activities	(1,354)	(1,025)	2,794
Net change in cash and cash equivalents	10	20	(289)
Cash and cash equivalents at beginning of period	23	3	292
Cash and cash equivalents at end of period	33	23	3
Repayments of BHE senior debt	0	0	250
Repayments of BHE subordinated debt	2,000	850	300
PacifiCorp [Member]
Cash flows from operating activities:
Net income (loss) attributable to parent	763	695	698
Adjustments to reconcile net income to net cash flows from operating activities:
Utilities Operating Expense, Depreciation and Amortization	770	757	726
Allowance for equity funds	(27)	(33)	(51)
Changes in regulatory assets and liabilities	122	63	(112)
Deferred income taxes and amortization of investment tax credits	139	172	297
Other, net	4	6	22
Changes in other operating assets and liabilities, net of effects from acquisitions:
Trade receivables and other assets	(25)	5	5
Derivative collateral, net	6	(47)	(16)
Increase (Decrease) in Inventories	(21)	(7)	37
Increase (Decrease) in Income Taxes Payable, Net of Income Taxes Receivable	0	116	(155)
Accounts payable and other liabilities	(163)	7	119
Net cash flows from operating activities	1,568	1,734	1,570
Cash flows from investing activities:
Capital expenditures	(903)	(916)	(1,066)
Other, net	34	(2)	(13)
Net cash flows from investing activities	(869)	(918)	(1,079)
Cash flows from financing activities:
Proceeds from Issuance of Long-term Debt	0	248	422
Net proceeds from (repayments of) short-term debt	250	0	20
Repayments of long-term debt and capital lease obligations (PacifiCorp)	(68)	(124)	(238)
Common stock dividends	(875)	(950)	(725)
Other, net	(1)	(1)	0
Net cash flows from financing activities	(694)	(827)	(521)
Net change in cash and cash equivalents	5	(11)	(30)
Cash and cash equivalents at beginning of period	12	23	53
Cash and cash equivalents at end of period	17	12	23
MidAmerican Energy Company [Member]
Cash flows from operating activities:
Net income (loss) attributable to parent	542	462	417
Adjustments to reconcile net income to net cash flows from operating activities:
Utilities Operating Expense, Depreciation and Amortization	479	407	351
Deferred income taxes and amortization of investment tax credits	361	275	300
Increase (Decrease) in Other Current Assets and Liabilities, Net	8	12	1
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net	47	49	47
Other, net	(91)	(58)	(57)
Changes in other operating assets and liabilities, net of effects from acquisitions:
Increase (Decrease) in Accounts and Other Receivables	61	(91)	3
Derivative collateral, net	5	33	(53)
Increase (Decrease) in Inventories	(27)	(53)	44
Pension and other postretirement benefit plans	(6)	(8)	(2)
Accrued property, income and other taxes	107	217	(252)
Increase (Decrease) in Accounts Payable	39	(76)	30
Increase (Decrease) in Other Current Assets and Liabilities, Net	8	12	1
Net cash flows from operating activities	1,403	1,351	823
Cash flows from investing activities:
Capital expenditures	(1,636)	(1,446)	(1,526)
Purchases of available-for-sale securities	(138)	(142)	(88)
Proceeds from sales of available-for-sale securities	158	135	80
Proceeds from Sales of Business, Affiliate and Productive Assets	0	0	8
Other, net	1	3	5
Net cash flows from investing activities	(1,615)	(1,450)	(1,521)
Cash flows from financing activities:
Proceeds from Issuance of Long-term Debt	62	649	840
Net proceeds from (repayments of) short-term debt	99	(50)	50
Repayments of Long-term Debt	(38)	(426)	(356)
Other, net	0	0	(1)
Net cash flows from financing activities	123	173	533
Net change in cash and cash equivalents	(89)	74	(165)
Cash and cash equivalents at beginning of period	103	29	194
Cash and cash equivalents at end of period	14	103	29
MidAmerican Funding, LLC and Subsidiaries [Domain]
Cash flows from operating activities:
Net income (loss) attributable to parent	532	458	409
Adjustments to reconcile net income to net cash flows from operating activities:
Utilities Operating Expense, Depreciation and Amortization	479	407	351
Deferred income taxes and amortization of investment tax credits	362	276	298
Increase (Decrease) in Other Current Assets and Liabilities, Net	8	12	0
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net	47	49	47
Other, net	(92)	(69)	(49)
Changes in other operating assets and liabilities, net of effects from acquisitions:
Increase (Decrease) in Accounts and Other Receivables	61	(93)	2
Derivative collateral, net	5	33	(53)
Increase (Decrease) in Inventories	(27)	(53)	44
Pension and other postretirement benefit plans	(6)	(8)	(2)
Accrued property, income and other taxes	107	213	(253)
Increase (Decrease) in Accounts Payable	39	(76)	30
Increase (Decrease) in Other Current Assets and Liabilities, Net	8	12	0
Net cash flows from operating activities	1,393	1,335	820
Cash flows from investing activities:
Capital expenditures	(1,636)	(1,446)	(1,526)
Purchases of available-for-sale securities	(138)	(142)	(88)
Proceeds from sales of available-for-sale securities	158	135	80
Proceeds from Sales of Business, Affiliate and Productive Assets	2	13	10
Other, net	0	2	5
Net cash flows from investing activities	(1,614)	(1,438)	(1,519)
Cash flows from financing activities:
Proceeds from Issuance of Long-term Debt	62	649	840
Net proceeds from (repayments of) short-term debt	99	(50)	50
Repayments of Long-term Debt	(38)	(426)	(356)
Increase (Decrease) in Notes Payable, Related Parties, Current	9	3	1
Other, net	1	0	0
Net cash flows from financing activities	133	176	535
Net change in cash and cash equivalents	(88)	73	(164)
Cash and cash equivalents at beginning of period	103	30	194
Cash and cash equivalents at end of period	15	103	30
Nevada Power Company [Member]
Cash flows from operating activities:
Net income (loss) attributable to parent	279	288	227
Adjustments to reconcile net income to net cash flows from operating activities:
Other Nonrecurring (Income) Expense	1	(3)	15
Utilities Operating Expense, Depreciation and Amortization	303	297	274
Allowance for equity funds	(2)	(4)	(1)
Changes in regulatory assets and liabilities	131	4	2
Deferred Energy Change	(21)	176	(44)
Amortization of Deferred Charges	(107)	36	79
Deferred income taxes and amortization of investment tax credits	78	162	130
Other, net	0	13	68
Changes in other operating assets and liabilities, net of effects from acquisitions:
Trade receivables and other assets	26	(40)	(19)
Increase (Decrease) in Inventories	7	9	(15)
Accrued property, income and other taxes	63	0	1
Accounts payable and other liabilities	13	(46)	(13)
Net cash flows from operating activities	771	892	704
Cash flows from investing activities:
Capital expenditures	(335)	(320)	(371)
Proceeds from Sale of Other Property, Plant, and Equipment	0	9	0
Other, net	0	10	0
Net cash flows from investing activities	(335)	(301)	(371)
Cash flows from financing activities:
Repayments of Long-term Debt	(224)	(262)	(9)
Common stock dividends	(469)	(13)	(230)
Net cash flows from financing activities	(693)	(275)	(239)
Net change in cash and cash equivalents	(257)	316	94
Cash and cash equivalents at beginning of period	536	220	126
Cash and cash equivalents at end of period	279	536	220
Sierra Pacific Power Company [Member]
Cash flows from operating activities:
Net income (loss) attributable to parent	84	83	87
Adjustments to reconcile net income to net cash flows from operating activities:
Other Nonrecurring (Income) Expense	5	0	14
Utilities Operating Expense, Depreciation and Amortization	118	113	105
Allowance for equity funds	1	(2)	(3)
Changes in regulatory assets and liabilities	(17)	(21)	(23)
Deferred Energy Change	53	81	(30)
Amortization of Deferred Charges	(54)	17	19
Deferred income taxes and amortization of investment tax credits	49	47	47
Other, net	0	(9)	20
Changes in other operating assets and liabilities, net of effects from acquisitions:
Trade receivables and other assets	7	15	28
Increase (Decrease) in Inventories	(6)	1	3
Accrued property, income and other taxes	(3)	0	0
Accounts payable and other liabilities	6	17	(21)
Net cash flows from operating activities	243	342	246
Cash flows from investing activities:
Capital expenditures	(194)	(252)	(186)
Other, net	0	2	0
Net cash flows from investing activities	(194)	(250)	(186)
Cash flows from financing activities:
Proceeds from Issuance of Long-term Debt	1,089	0	0
Repayments of Long-term Debt	(1,138)	(1)	1
Common stock dividends	(51)	(7)	(105)
Other, net	0	0	(1)
Net cash flows from financing activities	(100)	(8)	(105)
Net change in cash and cash equivalents	(51)	84	(45)
Cash and cash equivalents at beginning of period	106	22	67
Cash and cash equivalents at end of period	$ 55	$ 106	$ 22

Schedule I Condensed Balance Sh

Schedule I Condensed Balance Sheets (Paranthetical) - $ / shares shares in Millions	Dec. 31, 2016	Dec. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Common stock, par value	$ 0	$ 0
Common stock, shares authorized	115	115
Common stock, shares issued	77	77
Common stock, shares outstanding	77	77
Parent Company [Member]
Condensed Financial Statements, Captions [Line Items]
Common stock, par value	$ 0	$ 0
Common stock, shares authorized	115	115
Common stock, shares issued	77	77
Common stock, shares outstanding	77	77

Organization and Operations (No

Organization and Operations (Notes)	12 Months Ended
	Dec. 31, 2016
Segment Reporting Information [Line Items]
Organization and Operations	Organization and Operations Berkshire Hathaway Energy Company (" BHE ") is a holding company that owns subsidiaries principally engaged in energy businesses (collectively with its subsidiaries, the "Company"). BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway"). The Company's operations are organized and managed as eight business segments: PacifiCorp , MidAmerican Funding, LLC (" MidAmerican Funding ") (which primarily consists of MidAmerican Energy Company (" MidAmerican Energy ")), NV Energy, Inc. (" NV Energy ") (which primarily consists of Nevada Power Company (" Nevada Power ") and Sierra Pacific Power Company (" Sierra Pacific ")), Northern Powergrid Holdings Company (" Northern Powergrid ") (which primarily consists of Northern Powergrid (Northeast) Limited and Northern Powergrid (Yorkshire) plc), BHE Pipeline Group (which consists of Northern Natural Gas Company (" Northern Natural Gas ") and Kern River Gas Transmission Company (" Kern River ")), BHE Transmission (which consists of BHE Canada Holdings Corporation (" AltaLink ") (which primarily consists of AltaLink, L.P. ("ALP")) and BHE U.S. Transmission, LLC ), BHE Renewables and HomeServices of America, Inc. (collectively with its subsidiaries, "HomeServices"). The Company, through these businesses, owns four utility companies in the United States serving customers in 11 states, two electricity distribution companies in Great Britain, two interstate natural gas pipeline companies in the United States, an electric transmission business in Canada, interests in electric transmission businesses in the United States, a renewable energy business primarily selling power generated from solar, wind, geothermal and hydro sources under long-term contracts, the second largest residential real estate brokerage firm in the United States and one of the largest residential real estate brokerage franchise networks in the United States.
PacifiCorp [Member]
Segment Reporting Information [Line Items]
Organization and Operations	Organization and Operations PacifiCorp, which includes PacifiCorp and its subsidiaries, is a United States regulated electric utility company serving retail customers, including residential, commercial, industrial, irrigation and other customers in portions of Utah, Oregon, Wyoming, Washington, Idaho and California. PacifiCorp owns, or has interests in, a number of thermal, hydroelectric, wind-powered and geothermal generating facilities, as well as electric transmission and distribution assets. PacifiCorp also buys and sells electricity on the wholesale market with other utilities, energy marketing companies, financial institutions and other market participants. PacifiCorp is subject to comprehensive state and federal regulation. PacifiCorp's subsidiaries support its electric utility operations by providing coal mining services. PacifiCorp is an indirect subsidiary of Berkshire Hathaway Energy Company ("BHE"), a holding company based in Des Moines, Iowa that owns subsidiaries principally engaged in energy businesses. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").
MidAmerican Energy Company [Member]
Segment Reporting Information [Line Items]
Organization and Operations	MidAmerican Energy Company ("MidAmerican Energy") is a public utility with electric and natural gas operations and is the principal subsidiary of MHC Inc. ("MHC"). MHC is a holding company that conducts no business other than the ownership of its subsidiaries and related corporate services. MHC's nonregulated subsidiaries include Midwest Capital Group, Inc. and MEC Construction Services Co. MHC is the direct wholly owned subsidiary of MidAmerican Funding, LLC, ("MidAmerican Funding"), which is an Iowa limited liability company with Berkshire Hathaway Energy Company ("BHE") as its sole member. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").
MidAmerican Funding, LLC and Subsidiaries [Domain]
Segment Reporting Information [Line Items]
Organization and Operations	MidAmerican Funding, LLC ("MidAmerican Funding") is an Iowa limited liability company with Berkshire Hathaway Energy Company ("BHE") as its sole member. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway"). MidAmerican Funding's direct wholly owned subsidiary is MHC Inc. ("MHC"), which constitutes substantially all of MidAmerican Funding's assets, liabilities and business activities except those related to MidAmerican Funding's long-term debt securities. MHC conducts no business other than the ownership of its subsidiaries and related corporate services. MHC's principal subsidiary is MidAmerican Energy Company ("MidAmerican Energy"), a public utility with electric and natural gas operations. Direct, wholly owned nonregulated subsidiaries of MHC are Midwest Capital Group, Inc. ("Midwest Capital Group") and MEC Construction Services Co.
Nevada Power Company [Member]
Segment Reporting Information [Line Items]
Organization and Operations	Organization and Operations Nevada Power Company , together with its subsidiaries (" Nevada Power "), is a wholly owned subsidiary of NV Energy, Inc. (" NV Energy "), a holding company that also owns Sierra Pacific Power Company (" Sierra Pacific ") and certain other subsidiaries. Nevada Power is a United States regulated electric utility company serving retail customers, including residential, commercial and industrial customers primarily in the Las Vegas, North Las Vegas, Henderson and adjoining areas. NV Energy is an indirect wholly owned subsidiary of Berkshire Hathaway Energy Company (" BHE "). BHE is a holding company based in Des Moines, Iowa that owns subsidiaries principally engaged in energy businesses. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").
Sierra Pacific Power Company [Member]
Segment Reporting Information [Line Items]
Organization and Operations	Organization and Operations Sierra Pacific Power Company , together with its subsidiaries (" Sierra Pacific "), is a wholly owned subsidiary of NV Energy, Inc. (" NV Energy "), a holding company that also owns Nevada Power Company (" Nevada Power ") and certain other subsidiaries. Sierra Pacific is a United States regulated electric utility company serving retail customers, including residential, commercial and industrial customers and regulated retail natural gas customers primarily in northern Nevada. NV Energy is an indirect wholly owned subsidiary of Berkshire Hathaway Energy Company (" BHE "). BHE is a holding company based in Des Moines, Iowa that owns subsidiaries principally engaged in energy businesses. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

Summary of Significant Accounti

Summary of Significant Accounting Policies (Notes)	12 Months Ended
	Dec. 31, 2016
Allowance for Doubtful Accounts [Line Items]
Summary of Significant Accounting Policies [Text Block]	Summary of Significant Accounting Policies Basis of Consolidation and Presentation The Consolidated Financial Statements include the accounts of BHE and its subsidiaries in which it holds a controlling financial interest as of the financial statement date. The Consolidated Statements of Operations include the revenue and expenses of any acquired entities from the date of acquisition. Intercompany accounts and transactions have been eliminated. Use of Estimates in Preparation of Financial Statements The preparation of the Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; impairment of goodwill; recovery of long-lived assets; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; fair value of assets acquired and liabilities assumed in business combinations; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Consolidated Financial Statements. Accounting for the Effects of Certain Types of Regulation PacifiCorp, MidAmerican Energy, Nevada Power, Sierra Pacific, Northern Natural Gas, Kern River and ALP (the "Regulated Businesses") prepare their financial statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, the Regulated Businesses defer the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future regulated rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in regulated rates occur. The Company continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future regulated rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition that could limit the Regulated Businesses' ability to recover their costs. The Company believes the application of the guidance for regulated operations is appropriate and its existing regulatory assets and liabilities are probable of inclusion in future regulated rates. The evaluation reflects the current political and regulatory climate at both the federal, state and provincial levels. If it becomes no longer probable that the deferred costs or income will be included in future regulated rates, the related regulatory assets and liabilities will be recognized in net income, returned to customers or re-established as accumulated other comprehensive income (loss) ("AOCI"). Fair Value Measurements As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange. Cash Equivalents and Restricted Cash and Investments Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other current assets and investments and restricted cash and investments on the Consolidated Balance Sheets. Investments The Company's management determines the appropriate classification of investments in debt and equity securities at the acquisition date and reevaluates the classification at each balance sheet date. Investments and restricted cash and investments that management does not intend to use or is restricted from using in current operations are presented as noncurrent on the Consolidated Balance Sheets. Available-for-sale securities are carried at fair value with realized gains and losses, as determined on a specific identification basis, recognized in earnings and unrealized gains and losses recognized in AOCI, net of tax. Realized and unrealized gains and losses on securities in a trust related to the decommissioning of nuclear generation assets are recorded as a net regulatory liability since the Company expects to recover costs for these activities through regulated rates. Trading securities are carried at fair value with realized and unrealized gains and losses recognized in earnings. Held-to-maturity securities are carried at amortized cost, reflecting the ability and intent to hold the securities to maturity. The Company utilizes the equity method of accounting with respect to investments when it possesses the ability to exercise significant influence, but not control, over the operating and financial policies of the investee. The ability to exercise significant influence is presumed when an investor possesses more than 20% of the voting interests of the investee. This presumption may be overcome based on specific facts and circumstances that demonstrate the ability to exercise significant influence is restricted. In applying the equity method, the Company records the investment at cost and subsequently increases or decreases the carrying value of the investment by the Company's proportionate share of the net earnings or losses and other comprehensive income (loss) ("OCI") of the investee. The Company records dividends or other equity distributions as reductions in the carrying value of the investment. Certain equity investments are presented on the Consolidated Balance Sheets net of related investment tax credits. Investments gains and losses arise when investments are sold (as determined on a specific identification basis) or are other-than-temporarily impaired. If a decline in value of an investment below cost is deemed other than temporary, the cost of the investment is written down to fair value, with a corresponding charge to earnings. Factors considered in judging whether an impairment is other than temporary include: the financial condition, business prospects and creditworthiness of the issuer; the relative amount of the decline; the Company's ability and intent to hold the investment until the fair value recovers; and the length of time that fair value has been less than cost. Impairment losses on equity securities are charged to earnings. With respect to an investment in a debt security, any resulting impairment loss is recognized in earnings if the Company intends to sell, or expects to be required to sell, the debt security before its amortized cost is recovered. If the Company does not expect to ultimately recover the amortized cost basis even if it does not intend to sell the security, the credit loss component is recognized in earnings and any difference between fair value and the amortized cost basis, net of the credit loss, is reflected in OCI. For regulated investments, any impairment charge is offset by the establishment of a regulatory asset to the extent recovery in regulated rates is probable. Allowance for Doubtful Accounts Trade receivables are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on the Company's assessment of the collectibility of amounts owed to the Company by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. As of December 31, 2016 and 2015 , the allowance for doubtful accounts totaled $33 million and $31 million , respectively, and is included in trade receivables, net on the Consolidated Balance Sheets. Derivatives The Company employs a number of different derivative contracts, which may include forwards, futures, options, swaps and other agreements, to manage its commodity price, interest rate, and foreign currency exchange rate risk. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Cash collateral received from or paid to counterparties to secure derivative contract assets or liabilities in excess of amounts offset is included in other current assets on the Consolidated Balance Sheets. Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked-to-market and settled amounts are recognized as operating revenue or cost of sales on the Consolidated Statements of Operations. For the Company's derivatives not designated as hedging contracts, the settled amount is generally included in regulated rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in regulated rates are recorded as regulatory assets and liabilities. For the Company's derivatives not designated as hedging contracts and for which changes in fair value are not recorded as regulatory assets and liabilities, unrealized gains and losses are recognized on the Consolidated Statements of Operations as operating revenue for sales contracts; cost of sales and operating expense for purchase contracts and electricity, natural gas and fuel swap contracts; and other, net for interest rate swap derivatives. For the Company's derivatives designated as hedging contracts, the Company formally assesses, at inception and thereafter, whether the hedging contract is highly effective in offsetting changes in the hedged item. The Company formally documents hedging activity by transaction type and risk management strategy. Changes in the estimated fair value of a derivative contract designated and qualified as a cash flow hedge, to the extent effective, are included on the Consolidated Statements of Changes in Equity as AOCI, net of tax, until the contract settles and the hedged item is recognized in earnings. The Company discontinues hedge accounting prospectively when it has determined that a derivative contract no longer qualifies as an effective hedge, or when it is no longer probable that the hedged forecasted transaction will occur. When hedge accounting is discontinued because the derivative contract no longer qualifies as an effective hedge, future changes in the estimated fair value of the derivative contract are charged to earnings. Gains and losses related to discontinued hedges that were previously recorded in AOCI will remain in AOCI until the contract settles and the hedged item is recognized in earnings, unless it becomes probable that the hedged forecasted transaction will not occur at which time associated deferred amounts in AOCI are immediately recognized in earnings. Inventories Inventories consist mainly of fuel, which includes coal stocks, stored gas and fuel oil, totaling $402 million and $353 million as of December 31, 2016 and 2015 , respectively, and materials and supplies totaling $523 million and $529 million as of December 31, 2016 and 2015 , respectively. The cost of materials and supplies, coal stocks and fuel oil is determined primarily using the average cost method. The cost of stored gas is determined using either the last-in-first-out ("LIFO") method or the lower of average cost or market. With respect to inventories carried at LIFO cost, the replacement cost would be $27 million and $8 million higher as of December 31, 2016 and 2015 , respectively. Property, Plant and Equipment, Net General Additions to property, plant and equipment are recorded at cost. The Company capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs. Indirect construction costs include capitalized interest, including debt allowance for funds used during construction ("AFUDC"), and equity AFUDC, as applicable to the Regulated Businesses. The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. Additionally, MidAmerican Energy has regulatory arrangements in Iowa in which the carrying cost of certain utility plant has been reduced for amounts associated with electric returns on equity exceeding specified thresholds. Depreciation and amortization are generally computed by applying the composite or straight-line method based on either estimated useful lives or mandated recovery periods as prescribed by the Company's various regulatory authorities. Depreciation studies are completed by the Regulated Businesses to determine the appropriate group lives, net salvage and group depreciation rates. These studies are reviewed and rates are ultimately approved by the applicable regulatory commission. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as either a cost of removal regulatory liability or an ARO liability on the Consolidated Balance Sheets, depending on whether the obligation meets the requirements of an ARO. As actual removal costs are incurred, the associated liability is reduced. Generally when the Company retires or sells a component of regulated property, plant and equipment, it charges the original cost, net of any proceeds from the disposition, to accumulated depreciation. Any gain or loss on disposals of all other assets is recorded through earnings. Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of regulated facilities, is capitalized by the Regulated Businesses as a component of property, plant and equipment, with offsetting credits to the Consolidated Statements of Operations. AFUDC is computed based on guidelines set forth by the Federal Energy Regulatory Commission ("FERC") and the Alberta Utilities Commission ("AUC"). After construction is completed, the Company is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets. Asset Retirement Obligations The Company recognizes AROs when it has a legal obligation to perform decommissioning, reclamation or removal activities upon retirement of an asset. The Company's AROs are primarily related to the decommissioning of nuclear generating facilities and obligations associated with its other generating facilities and offshore natural gas pipelines. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to property, plant and equipment, net) and for accretion of the ARO liability due to the passage of time. For the Regulated Businesses, the difference between the ARO liability, the corresponding ARO asset included in property, plant and equipment, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability. Impairment The Company evaluates long-lived assets for impairment, including property, plant and equipment, when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable or the assets are being held for sale. Upon the occurrence of a triggering event, the asset is reviewed to assess whether the estimated undiscounted cash flows expected from the use of the asset plus the residual value from the ultimate disposal exceeds the carrying value of the asset. If the carrying value exceeds the estimated recoverable amounts, the asset is written down to the estimated fair value and any resulting impairment loss is reflected on the Consolidated Statements of Operations. The impacts of regulation are considered when evaluating the carrying value of regulated assets. Goodwill Goodwill represents the excess of the purchase price over the fair value of identifiable net assets acquired in business combinations. The Company evaluates goodwill for impairment at least annually and completed its annual review as of October 31. When evaluating goodwill for impairment, the Company estimates the fair value of the reporting unit. If the carrying amount of a reporting unit, including goodwill, exceeds the estimated fair value, then the identifiable assets, including identifiable intangible assets, and liabilities of the reporting unit are estimated at fair value as of the current testing date. The excess of the estimated fair value of the reporting unit over the current estimated fair value of net assets establishes the implied value of goodwill. The excess of the recorded goodwill over the implied goodwill value is charged to earnings as an impairment loss. Significant judgment is required in estimating the fair value of the reporting unit and performing goodwill impairment tests. The Company uses a variety of methods to estimate a reporting unit's fair value, principally discounted projected future net cash flows. Key assumptions used include, but are not limited to, the use of estimated future cash flows; multiples of earnings; and an appropriate discount rate. In estimating future cash flows, the Company incorporates current market information, as well as historical factors. As such, the determination of fair value incorporates significant unobservable inputs. During 2016 , 2015 and 2014 , the Company did not record any goodwill impairments. The Company records goodwill adjustments for (a) the tax benefit associated with the excess of tax-deductible goodwill over the reported amount of goodwill and (b) changes to the purchase price allocation prior to the end of the measurement period, which is not to exceed one year from the acquisition date. Revenue Recognition Energy Businesses Revenue from energy business customers is recognized as electricity or natural gas is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31, 2016 and 2015 , unbilled revenue was $643 million and $660 million , respectively, and is included in trade receivables, net on the Consolidated Balance Sheets. Rates for energy businesses are established by regulators or contractual arrangements. When preliminary regulated rates are permitted to be billed prior to final approval by the applicable regulator, certain revenue collected may be subject to refund and a liability for estimated refunds is accrued. The Company records sales, franchise and excise taxes collected directly from customers and remitted directly to the taxing authorities on a net basis on the Consolidated Statements of Operations. Real Estate Commission Revenue, Mortgage Revenue and Franchise Royalty Fees Commission revenue from real estate brokerage transactions and related amounts due to agents are recognized when a real estate transaction is closed. Title and escrow closing fee revenue from real estate transactions and related amounts due to the title insurer are recognized at closing. Mortgage fee revenue consists of amounts earned related to application and underwriting fees, and fees on canceled loans. Fees associated with the origination and acquisition of mortgage loans are recognized as earned. Franchise royalty fees are based on a percentage of commissions earned by franchisees on real estate sales and are recognized when the sale closes. Unamortized Debt Premiums, Discounts and Debt Issuance Costs Premiums, discounts and debt issuance costs incurred for the issuance of long-term debt are amortized over the term of the related financing using the effective interest method. Foreign Currency The accounts of foreign-based subsidiaries are measured in most instances using the local currency of the subsidiary as the functional currency. Revenue and expenses of these businesses are translated into United States dollars at the average exchange rate for the period. Assets and liabilities are translated at the exchange rate as of the end of the reporting period. Gains or losses from translating the financial statements of foreign-based operations are included in equity as a component of AOCI. Gains or losses arising from transactions denominated in a currency other than the functional currency of the entity that is party to the transaction are included in earnings. Income Taxes Berkshire Hathaway includes the Company in its United States federal income tax return. The Company's provision for income taxes has been computed on a stand-alone basis. Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of OCI are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with income tax benefits and expense for certain property-related basis differences and other various differences that PacifiCorp, MidAmerican Energy, Nevada Power and Sierra Pacific (the "Utilities") are required to pass on to their customers in most state jurisdictions are charged or credited directly to a regulatory asset or liability. As of December 31, 2016 and 2015 , these amounts were recognized as regulatory assets of $1.6 billion and $1.5 billion , respectively, and regulatory liabilities of $25 million and $29 million , respectively, and will be included in regulated rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Valuation allowances are established when necessary to reduce deferred income tax assets to the amount that is more-likely-than-not to be realized. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties or as prescribed by various regulatory jurisdictions. The Company has not established deferred income taxes on the undistributed foreign earnings of Northern Powergrid or AltaLink or the related currency translation adjustment that have been determined by management to be reinvested indefinitely. The cumulative undistributed foreign earnings were approximately $3.0 billion as of December 31, 2016 . The Company periodically evaluates its capital requirements. If circumstances change in the future and a portion of Northern Powergrid's or AltaLink's undistributed earnings were repatriated, the dividends would be subject to taxation in the United States. However, any United States income tax liability would be offset, in part, by available United States income tax credits with respect to corporate income taxes previously paid in the United Kingdom and Canada. Because of the availability of foreign income tax credits, it is not practicable to determine the United States income tax liability that would be recognized if such cumulative earnings were not reinvested indefinitely. The Company has established deferred income taxes on all other undistributed foreign earnings. If opportunities become available to repatriate any available cash without triggering incremental United States income tax expense, the Company may distribute certain foreign earnings of Northern Powergrid and AltaLink. In determining the Company's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by the Company's various regulatory jurisdictions. The Company's income tax returns are subject to continuous examinations by federal, state, local and foreign income tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. The Company recognizes the tax benefit from an uncertain tax position only if it is more-likely-than-not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Consolidated Financial Statements from such a position are measured based on the largest benefit that is more-likely-than-not to be realized upon ultimate settlement. Although the ultimate resolution of the Company's federal, state, local and foreign income tax examinations is uncertain, the Company believes it has made adequate provisions for these income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on the Company's consolidated financial results. The Company's unrecognized tax benefits are primarily included in accrued property, income and other taxes and other long-term liabilities on the Consolidated Balance Sheets. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Consolidated Statements of Operations. New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. The material impacts currently identified include recording the unrealized gains and losses on available-for-sale securities in the Consolidated Statements of Operations as opposed to OCI. For the years ended December 31, 2016, 2015 and 2014, these amounts, net of tax, were $(30) million , $225 million and $(134) million , respectively. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued
PacifiCorp [Member]
Allowance for Doubtful Accounts [Line Items]
Summary of Significant Accounting Policies [Text Block]	Summary of Significant Accounting Policies Basis of Consolidation and Presentation The Consolidated Financial Statements include the accounts of PacifiCorp and its subsidiaries in which it holds a controlling financial interest as of the financial statement date. Intercompany accounts and transactions have been eliminated. Use of Estimates in Preparation of Financial Statements The preparation of the Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Consolidated Financial Statements. Accounting for the Effects of Certain Types of Regulation PacifiCorp prepares its financial statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, PacifiCorp defers the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in rates occur. PacifiCorp continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition that could limit PacifiCorp's ability to recover its costs. PacifiCorp believes the application of the guidance for regulated operations is appropriate and its existing regulatory assets and liabilities are probable of inclusion in future rates. The evaluation reflects the current political and regulatory climate at both the federal and state levels. If it becomes no longer probable that the deferred costs or income will be included in future rates, the related regulatory assets and liabilities will be written off to net income or re-established as accumulated other comprehensive income (loss) ("AOCI"). Fair Value Measurements As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange. Cash Equivalents and Restricted Cash and Investments Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other current assets and other assets on the Consolidated Balance Sheets. Investments Available-for-sale securities are carried at fair value with realized gains and losses, as determined on a specific identification basis, recognized in earnings and unrealized gains and losses recognized in AOCI, net of tax. As of December 31, 2016 and 2015 , PacifiCorp had no unrealized gains and losses on available-for-sale securities. Trading securities are carried at fair value with realized and unrealized gains and losses recognized in earnings. PacifiCorp utilizes the equity method of accounting with respect to investments when it possesses the ability to exercise significant influence, but not control, over the operating and financial policies of the investee. The ability to exercise significant influence is presumed when an investor possesses more than 20% of the voting interests of the investee. This presumption may be overcome based on specific facts and circumstances that demonstrate the ability to exercise significant influence is restricted. In applying the equity method, PacifiCorp records the investment at cost and subsequently increases or decreases the carrying value of the investment by PacifiCorp's proportionate share of the net earnings or losses and other comprehensive income (loss) ("OCI") of the investee. PacifiCorp records dividends or other equity distributions as reductions in the carrying value of the investment. Allowance for Doubtful Accounts Accounts receivable are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on PacifiCorp's assessment of the collectibility of amounts owed to PacifiCorp by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. The change in the balance of the allowance for doubtful accounts, which is included in accounts receivable, net on the Consolidated Balance Sheets, is summarized as follows for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 7 $ 7 $ 8 Charged to operating costs and expenses, net 12 10 11 Write-offs, net (12 ) (10 ) (12 ) Ending balance $ 7 $ 7 $ 7 Derivatives PacifiCorp employs a number of different derivative contracts, which may include forwards, options, swaps and other agreements, to manage price risk for electricity, natural gas and other commodities and interest rate risk. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked-to-market and settled amounts are recognized as operating revenue or energy costs on the Consolidated Statements of Operations. For PacifiCorp's derivative contracts, the settled amount is generally included in rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in rates are recorded as regulatory liabilities or assets. For a derivative contract not probable of inclusion in rates, changes in the fair value are recognized in earnings. Inventories Inventories consist of materials and supplies, coal stocks, natural gas and fuel oil, which are stated at the lower of average cost or net realizable value. Property, Plant and Equipment, Net General Additions to property, plant and equipment are recorded at cost. PacifiCorp capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs, which include debt and equity allowance for funds used during construction ("AFUDC"). The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. Depreciation and amortization are generally computed on the straight-line method based on composite asset class lives prescribed by PacifiCorp's various regulatory authorities or over the assets' estimated useful lives. Depreciation studies are completed periodically to determine the appropriate composite asset class lives, net salvage and depreciation rates. These studies are reviewed and rates are ultimately approved by the various regulatory authorities. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as either a cost of removal regulatory liability or an ARO liability on the Consolidated Balance Sheets, depending on whether the obligation meets the requirements of an ARO. As actual removal costs are incurred, the associated liability is reduced. Generally when PacifiCorp retires or sells a component of regulated property, plant and equipment, it charges the original cost, net of any proceeds from the disposition, to accumulated depreciation. Any gain or loss on disposals of all other assets is recorded through earnings. Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of property, plant and equipment, is capitalized as a component of property, plant and equipment, with offsetting credits to the Consolidated Statements of Operations. AFUDC is computed based on guidelines set forth by the Federal Energy Regulatory Commission ("FERC"). After construction is completed, PacifiCorp is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets. Asset Retirement Obligations PacifiCorp recognizes AROs when it has a legal obligation to perform decommissioning, reclamation or removal activities upon retirement of an asset. PacifiCorp's AROs are primarily associated with its generating facilities. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to property, plant and equipment, net) and for accretion of the ARO liability due to the passage of time. The difference between the ARO liability, the corresponding ARO asset included in property, plant and equipment, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability. Impairment The Company evaluates long-lived assets for impairment, including property, plant and equipment, when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable or the assets are being held for sale. Upon the occurrence of a triggering event, the asset is reviewed to assess whether the estimated undiscounted cash flows expected from the use of the asset plus the residual value from the ultimate disposal exceeds the carrying value of the asset. If the carrying value exceeds the estimated recoverable amounts, the asset is written down to the estimated fair value and any resulting impairment loss is reflected on the Consolidated Statements of Operations. The impacts of regulation are considered when evaluating the carrying value of regulated assets. Revenue Recognition Revenue is recognized as electricity is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31, 2016 and 2015 , unbilled revenue was $275 million and $245 million , respectively, and is included in accounts receivable, net on the Consolidated Balance Sheets. Rates charged are established by regulators or contractual arrangements. The determination of sales to individual customers is based on the reading of the customer's meter, which is performed on a systematic basis throughout the month. At the end of each month, energy provided to customers since the date of the last meter reading is estimated, and the corresponding unbilled revenue is recorded. The estimate is reversed in the following month and actual revenue is recorded based on subsequent meter readings. The monthly unbilled revenues of PacifiCorp are determined by the estimation of unbilled energy provided during the period, the assignment of unbilled energy provided to customer classes and the average rate per customer class. Factors that can impact the estimate of unbilled energy include, but are not limited to, seasonal weather patterns, total volumes supplied to the system, line losses, economic impacts and composition of sales among customer classes. PacifiCorp records sales, franchise and excise taxes collected directly from customers and remitted directly to the taxing authorities on a net basis on the Consolidated Statements of Operations. Income Taxes Berkshire Hathaway includes PacifiCorp in its United States federal income tax return. Consistent with established regulatory practice, PacifiCorp's provision for income taxes has been computed on a stand-alone basis. Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of OCI are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with income tax benefits and expense for certain property-related basis differences and other various differences that PacifiCorp is required to pass on to its customers are charged or credited directly to a regulatory asset or liability. These amounts were recognized as regulatory assets of $421 million and $437 million as of December 31, 2016 and 2015 , respectively, and regulatory liabilities of $9 million and $12 million as of December 31, 2016 and 2015 , respectively, and will be included in rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Valuation allowances are established when necessary to reduce deferred income tax assets to the amount that is more likely than not to be realized. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties or as prescribed by various regulatory jurisdictions. Investment tax credits are included in other long-term liabilities on the Consolidated Balance Sheets and were $18 million and $23 million as of December 31, 2016 and 2015 , respectively. In determining PacifiCorp's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by PacifiCorp's various regulatory jurisdictions. PacifiCorp's income tax returns are subject to continuous examinations by federal, state and local income tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. PacifiCorp recognizes the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Consolidated Financial Statements from such a position are measured based on the largest benefit that is more likely than not to be realized upon ultimate settlement. Although the ultimate resolution of PacifiCorp's federal, state and local income tax examinations is uncertain, PacifiCorp believes it has made adequate provisions for these income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on PacifiCorp's consolidated financial results. PacifiCorp's unrecognized tax benefits are primarily included in other long-term liabilities on the Consolidated Balance Sheets. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Consolidated Statements of Operations. Segment Information PacifiCorp currently has one segment, which includes its regulated electric utility operations. New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. The impact of this update is immaterial to PacifiCorp's Consolidated Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. PacifiCorp currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what PacifiCorp has the right to invoice as it corresponds directly with the value to the customer of PacifiCorp’s performance to date. PacifiCorp’s current plan is to quantitatively disaggregate revenue in the required financial statement footnote by customer class and jurisdiction.
MidAmerican Energy Company [Member]
Allowance for Doubtful Accounts [Line Items]
Summary of Significant Accounting Policies [Text Block]	Use of Estimates in Preparation of Financial Statements The preparation of the Financial Statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Financial Statements. A ccounting for the Effects of Certain Types of Regulation MidAmerican Energy's utility operations are subject to the regulation of the Iowa Utilities Board ("IUB"), the Illinois Commerce Commission ("ICC"), the South Dakota Public Utilities Commission, and the Federal Energy Regulatory Commission ("FERC"). MidAmerican Energy's accounting policies and the accompanying Financial Statements conform to GAAP applicable to rate-regulated enterprises and reflect the effects of the ratemaking process. MidAmerican Energy prepares its financial statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, MidAmerican Energy defers the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future regulated rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in regulated rates occur. MidAmerican Energy continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future regulated rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition, that could limit MidAmerican Energy's ability to recover its costs. MidAmerican Energy believes the application of the guidance for regulated operations is appropriate, and its existing regulatory assets and liabilities are probable of inclusion in future regulated rates. The evaluation reflects the current political and regulatory climate at both the federal and state levels. If it becomes no longer probable that the deferred costs or income will be included in future regulated rates, the related regulatory assets and liabilities will be written off to net income, returned to customers or re-established as accumulated other comprehensive income (loss) ("AOCI"). Fair Value Measurements As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange. Cash Equivalents and Restricted Cash and Investments Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other current assets and restricted cash and investments on the Balance Sheets. Investments MidAmerican Energy's management determines the appropriate classification of investments in debt and equity securities at the acquisition date and reevaluates the classification at each balance sheet date. Investments that management does not intend to use or is restricted from using in current operations are presented as noncurrent on the Balance Sheets. Available-for-sale securities are carried at fair value with realized gains and losses, as determined on a specific identification basis, recognized in earnings and unrealized gains and losses recognized in AOCI, net of tax. Realized and unrealized gains and losses on securities in a trust related to the decommissioning of the Quad Cities Generating Station Units 1 and 2 ("Quad Cities Station") are recorded as a net regulatory liability because MidAmerican Energy expects to recover costs for these activities through regulated rates. Held-to-maturity securities are carried at amortized cost, reflecting the ability and intent to hold the securities to maturity. Investments gains and losses arise when investments are sold (as determined on a specific identification basis) or are other-than-temporarily impaired. If a decline in value of an investment below cost is deemed other than temporary, the cost of the investment is written down to fair value, with a corresponding charge to earnings. Factors considered in judging whether an impairment is other than temporary include: the financial condition, business prospects and creditworthiness of the issuer; the relative amount of the decline; MidAmerican Energy's ability and intent to hold the investment until the fair value recovers; and the length of time that fair value has been less than cost. Impairment losses on equity securities are charged to earnings. With respect to an investment in a debt security, any resulting impairment loss is recognized in earnings if MidAmerican Energy intends to sell, or expects to be required to sell, the debt security before its amortized cost is recovered. If MidAmerican Energy does not expect to ultimately recover the amortized cost basis even if it does not intend to sell the security, the credit loss component is recognized in earnings and any difference between fair value and the amortized cost basis, net of the credit loss, is reflected in other comprehensive income (loss) ("OCI"). For regulated investments, any impairment charge is offset by the establishment of a regulatory asset to the extent recovery in regulated rates is probable. Allowance for Doubtful Accounts Receivables are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on MidAmerican Energy's assessment of the collectibility of amounts owed to it by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. As of December 31, 2016 and 2015 , the allowance for doubtful accounts totaled $7 million and $6 million , respectively, and is included in receivables, net on the Balance Sheets. Derivatives MidAmerican Energy employs a number of different derivative contracts, including forwards, futures, options, swaps and other agreements, to manage price risk for electricity, natural gas and other commodities, and interest rate risk. Derivative contracts are recorded on the Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Cash collateral received from or paid to counterparties to secure derivative contract assets or liabilities in excess of amounts offset is included in other current assets on the Balance Sheets. Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked to market, and settled amounts are recognized as operating revenue or cost of sales on the Statements of Operations. For MidAmerican Energy's derivatives not designated as hedging contracts, the settled amount is generally included in regulated rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in regulated rates are recorded as regulatory assets and liabilities. For MidAmerican Energy's derivatives designated as hedging contracts, MidAmerican Energy formally assesses, at inception and thereafter, whether the hedging contract is highly effective in offsetting changes in the hedged item. MidAmerican Energy formally documents hedging activity by transaction type and risk management strategy. Changes in the estimated fair value of a derivative contract designated and qualified as a cash flow hedge, to the extent effective, are included on the Statements of Changes in Equity as AOCI, net of tax, until the contract settles and the hedged item is recognized in earnings. All of MidAmerican Energy's derivatives designated as cash flow hedges and the related AOCI were transferred to a subsidiary of BHE on January 1, 2016, as discussed in Note 3 . Inventories Inventories consist mainly of coal stocks, totaling $137 million and $102 million as of December 31, 2016 and 2015 , respectively, materials and supplies, totaling $99 million and $105 million as of December 31, 2016 and 2015 , respectively, and natural gas in storage, totaling $24 million and $27 million as of December 31, 2016 and 2015 , respectively. The cost of materials and supplies, coal stocks and fuel oil is determined using the average cost method. The cost of stored natural gas is determined using the last-in-first-out method. With respect to stored natural gas, the replacement cost would be $27 million and $8 million higher as of December 31, 2016 and 2015 , respectively. Utility Plant, Net General Additions to utility plant are recorded at cost. MidAmerican Energy capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs. Indirect construction costs include debt allowance for funds used during construction ("AFUDC") and equity AFUDC. The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. Additionally, MidAmerican Energy has regulatory arrangements in Iowa in which the carrying cost of certain utility plant has been reduced for amounts associated with electric returns on equity exceeding specified thresholds. Amounts expensed under this arrangement are included as a component of depreciation and amortization. Depreciation and amortization for MidAmerican Energy's utility operations are computed by applying the composite or straight-line method based on either estimated useful lives or mandated recovery periods as prescribed by its various regulatory authorities. Depreciation studies are completed by MidAmerican Energy to determine the appropriate group lives, net salvage and group depreciation rates. These studies are reviewed and rates are ultimately approved by the applicable regulatory commission. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as either a cost of removal regulatory liability or an ARO liability on the Balance Sheets, depending on whether the obligation meets the requirements of an ARO. As actual removal costs are incurred, the associated liability is reduced. Generally, when MidAmerican Energy retires or sells a component of utility plant, it charges the original cost, net of any proceeds from the disposition to accumulated depreciation. Any gain or loss on disposals of nonregulated assets is recorded through earnings. Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of its regulated facilities, is capitalized by MidAmerican Energy as a component of utility plant, with offsetting credits to the Statements of Operations. AFUDC is computed based on guidelines set forth by the FERC. After construction is completed, MidAmerican Energy is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets. Asset Retirement Obligations MidAmerican Energy recognizes AROs when it has a legal obligation to perform decommissioning or removal activities upon retirement of an asset. MidAmerican Energy's AROs are primarily related to decommissioning of the Quad Cities Station and obligations associated with its other generating facilities. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to utility plant) and for accretion of the ARO liability due to the passage of time. The difference between the ARO liability, the corresponding ARO asset included in utility plant, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability. Impairment MidAmerican Energy evaluates long-lived assets for impairment, including utility plant, when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable or the assets are being held for sale. Upon the occurrence of a triggering event, the asset is reviewed to assess whether the estimated undiscounted cash flows expected from the use of the asset plus the residual value from the ultimate disposal exceeds the carrying value of the asset. If the carrying value exceeds the estimated recoverable amounts, the asset is written down to the estimated fair value. The impacts of regulation are considered when evaluating the carrying value of regulated assets. For all other assets, any resulting impairment loss is reflected on the Statements of Operations. Revenue Recognition Revenue from electric and natural gas customers is recognized as electricity or natural gas is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31, 2016 and 2015 , unbilled revenue was $87 million and $138 million , respectively, and is included in receivables, net on the Balance Sheets. The determination of customer billings is based on a systematic reading of customer meters and applicable rates. At the end of each month, amounts of energy provided to customers since the date of the last meter reading are estimated, and the corresponding unbilled revenue is recorded. Factors that can impact the estimate of unbilled energy include, but are not limited to, seasonal weather patterns, total volumes supplied to the system, line losses, economic impacts and composition of customer classes. Unbilled revenue is reversed in the following month and billed revenue is recorded based on the subsequent meter readings. All of MidAmerican Energy's regulated retail electric and gas sales are subject to energy adjustment clauses. MidAmerican Energy also has costs that are recovered, at least in part, through bill riders, including demand-side management and certain transmission costs. The clauses and riders allow MidAmerican Energy to adjust the amounts charged for electric and gas service as the related costs change. The costs recovered in revenue through use of the adjustment clauses and bill riders are charged to expense in the same year the related revenue is recognized. At any given time, these costs may be over or under collected from customers. The total under collection included in receivables at December 31, 2016 and 2015 , was $31 million and $17 million , respectively. MidAmerican Energy collects from its customers sales and excise taxes assessed by governmental authorities on transactions with customers and later remits the collected taxes to the appropriate authority. If the obligation to pay a particular tax resides with the customer, MidAmerican Energy reports such taxes collected on a net basis and, accordingly, they do not affect the Statement of Operations. Taxes for which the obligation resides with MidAmerican Energy are reported on a gross basis in operating revenue and operating expenses. The amounts reported on a gross basis are not material. Unamortized Debt Premiums, Discounts and Issuance Costs Premiums, discounts and issuance costs incurred for the issuance of long-term debt are amortized over the term of the related financing using the effective interest method. Income Taxes Berkshire Hathaway includes MidAmerican Funding and MidAmerican Energy in its United States federal income tax return. MidAmerican Funding's and MidAmerican Energy's provisions for income taxes have been computed on a stand-alone basis. Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of OCI are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with income tax benefits and expense for certain property-related basis differences and other various differences that MidAmerican Energy is required to pass on to its customers in Iowa are charged or credited directly to a regulatory asset or liability. As of December 31, 2016 and 2015 , these amounts were recognized as a net regulatory asset totaling $985 million and $858 million , respectively, and will be included in regulated rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties or as prescribed by various regulatory jurisdictions. In determining MidAmerican Funding's and MidAmerican Energy's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by MidAmerican Energy's various regulatory jurisdictions. MidAmerican Funding's and MidAmerican Energy's income tax returns are subject to continuous examinations by federal, state and local tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. MidAmerican Funding and MidAmerican Energy recognize the tax benefit from an uncertain tax position only if it is more-likely-than-not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Consolidated Financial Statements from such a position are measured based on the largest benefit that is more-likely-than-not to be realized upon ultimate settlement. Although the ultimate resolution of their federal, state and local income tax examinations is uncertain, each company believes it has made adequate provisions for its income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on its consolidated financial results. MidAmerican Funding's and MidAmerican Energy's unrecognized tax benefits are primarily included in taxes accrued and other long-term liabilities on their respective Consolidated Balance Sheets. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Consolidated Statements of Operations. New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively, wherein the statement of cash flows of each period presented should be adjusted to reflect the new guidance. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No.2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. MidAmerican Energy currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what MidAmerican Energy has the right to invoice as it corresponds directly with the value to the customer of MidAmerican Energy’s performance to date. MidAmerican Energy's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by jurisdiction for each segment.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Allowance for Doubtful Accounts [Line Items]
Summary of Significant Accounting Policies [Text Block]	Summary of Significant Accounting Policies In addition to the following significant accounting policies, refer to Note 2 of MidAmerican Energy's Notes to Financial Statements for significant accounting policies of MidAmerican Funding. Basis of Consolidation and Presentation The Consolidated Financial Statements include the accounts of MidAmerican Funding and its subsidiaries in which it held a controlling financial interest as of the financial statement date. Intercompany accounts and transactions have been eliminated, other than those between rate-regulated operations. Goodwill Goodwill represents the excess of the purchase price over the fair value of identifiable net assets acquired when MidAmerican Funding purchased MHC. MidAmerican Funding evaluates goodwill for impairment at least annually and completed its annual review as of October 31. When evaluating goodwill for impairment, MidAmerican Funding estimates the fair value of the reporting unit. If the carrying amount of a reporting unit, including goodwill, exceeds the estimated fair value, then the identifiable assets, including identifiable intangible assets, and liabilities of the reporting unit are estimated at fair value as of the current testing date. The excess of the estimated fair value of the reporting unit over the current estimated fair value of net assets establishes the implied value of goodwill. The excess of the recorded goodwill over the implied goodwill value is charged to earnings as an impairment loss. Significant judgment is required in estimating the fair value of the reporting unit and performing goodwill impairment tests. MidAmerican Funding uses a variety of methods to estimate a reporting unit's fair value, principally discounted projected future net cash flows. Key assumptions used include, but are not limited to, the use of estimated future cash flows; multiples of earnings; and an appropriate discount rate. In estimating future cash flows, MidAmerican Funding incorporates current market information, as well as historical factors. As such, the determination of fair value incorporates significant unobservable inputs. During 2016 , 2015 and 2014 , MidAmerican Funding did not record any goodwill impairments.
Nevada Power Company [Member]
Allowance for Doubtful Accounts [Line Items]
Summary of Significant Accounting Policies [Text Block]	Summary of Significant Accounting Policies Basis of Consolidation and Presentation The Consolidated Financial Statements include the accounts of Nevada Power Company and its subsidiaries in which it holds a controlling financial interest as of the financial statement date. Intercompany accounts and transactions have been eliminated. The Consolidated Statements of Comprehensive Income have been omitted as net income equals comprehensive income for the years ended December 31, 2016 , 2015 and 2014 . Certain amounts in the prior period Consolidated Financial Statements have been reclassified to conform to the current period presentation. Such reclassifications did not impact previously reported operating income, net income or retained earnings. Use of Estimates in Preparation of Financial Statements The preparation of the Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; recovery of long-lived assets; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Consolidated Financial Statements. Accounting for the Effects of Certain Types of Regulation Nevada Power prepares its Consolidated Financial Statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, Nevada Power defers the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future regulated rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in regulated rates occur. Nevada Power continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future regulated rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition that could limit Nevada Power 's ability to recover its costs. Nevada Power believes the application of the guidance for regulated operations is appropriate and its existing regulatory assets and liabilities are probable of inclusion in future regulated rates. The evaluation reflects the current political and regulatory climate at both the federal and state levels. If it becomes no longer probable that the deferred costs or income will be included in future regulated rates, the related regulatory assets and liabilities will be written off to net income, returned to customers or re-established as accumulated other comprehensive income (loss). Fair Value Measurements As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange. Cash Equivalents and Restricted Cash and Investments Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other assets and other current assets on the Consolidated Balance Sheets. Allowance for Doubtful Accounts Accounts receivable are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on Nevada Power 's assessment of the collectibility of amounts owed to Nevada Power by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. Nevada Power also has the ability to assess deposits on customers who have delayed payments or who are deemed to be a credit risk. The change in the balance of the allowance for doubtful accounts, which is included in accounts receivable, net on the Consolidated Balance Sheets, is summarized as follows for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 13 $ 14 $ 8 Charged to operating costs and expenses, net 16 16 14 Write-offs, net (17 ) (17 ) (8 ) Ending balance $ 12 $ 13 $ 14 Derivatives Nevada Power employs a number of different derivative contracts, which may include forwards, futures, options, swaps and other agreements, to manage its commodity price and interest rate risk. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked‑to‑market and settled amounts are recognized as cost of fuel, energy and capacity on the Consolidated Statements of Operations. For Nevada Power 's derivative contracts, the settled amount is generally included in regulated rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in regulated rates are recorded as regulatory assets and liabilities. For a derivative contract not probable of inclusion in rates, changes in the fair value are recognized in earnings. Inventories Inventories consist mainly of materials and supplies totaling $60 million and $58 million as of December 31 , 2016 and 2015 , respectively, and fuel, which includes coal stock, stored natural gas and fuel oil, totaling $13 million and $22 million as of December 31 , 2016 and 2015 , respectively. The cost is determined using the average cost method. Materials are charged to inventory when purchased and are expensed or capitalized to construction work in process, as appropriate, when used. Fuel costs are recovered from retail customers through the base tariff energy rates and deferred energy accounting adjustment charges approved by the Public Utilities Commission of Nevada ("PUCN"). Property, Plant and Equipment, Net General Additions to property, plant and equipment are recorded at cost. Nevada Power capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs. Indirect construction costs include debt allowance for funds used during construction ("AFUDC"), and equity AFUDC, as applicable. The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. The cost of repairs and minor replacements are charged to expense when incurred with the exception of costs for generation plant maintenance under certain long-term service agreements. Costs under these agreements are expensed straight-line over the term of the agreements as approved by the PUCN. Depreciation and amortization are generally computed by applying the composite or straight-line method based on either estimated useful lives or mandated recovery periods as prescribed by Nevada Power 's various regulatory authorities. Depreciation studies are completed by Nevada Power to determine the appropriate group lives, net salvage and group depreciation rates. These studies are reviewed and rates are ultimately approved by the applicable regulatory commission. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as a non-current regulatory liability on the Consolidated Balance Sheets. As actual removal costs are incurred, the associated liability is reduced. Generally when Nevada Power retires or sells a component of regulated property, plant and equipment depreciated using the composite method, it charges the original cost, net of any proceeds from the disposition, to accumulated depreciation. Any gain or loss on disposals of all other assets is recorded through earnings with the exception of material gains or losses on regulated property, plant and equipment depreciated on a straight-line basis, which is then recorded to a regulatory asset or liability. Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of regulated facilities, are capitalized as a component of property, plant and equipment, with offsetting credits to the Consolidated Statements of Operations. The rate applied to construction costs is the lower of the PUCN allowed rate of return and rates computed based on guidelines set forth by the Federal Energy Regulatory Commission ("FERC"). After construction is completed, Nevada Power is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets. Nevada Power 's AFUDC rate used during 2016 and 2015 was 8.09% . Asset Retirement Obligations Nevada Power recognizes AROs when it has a legal obligation to perform decommissioning, reclamation or removal activities upon retirement of an asset. Nevada Power 's AROs are primarily associated with its generating facilities. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to property, plant and equipment, net) and for accretion of the ARO liability due to the passage of time. The difference between the ARO liability, the corresponding ARO asset included in property, plant and equipment, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability on the Consolidated Balance Sheets. The costs are not recovered in rates until the work has been completed. Impairment of Long-Lived Assets Nevada Power evaluates long-lived assets for impairment, including property, plant and equipment, when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable or the assets are being held for sale. Upon the occurrence of a triggering event, the asset is reviewed to assess whether the estimated cash flows expected from the use of the asset plus the residual value from the ultimate disposal exceeds the carrying value of the asset. If the carrying value exceeds the estimated recoverable amounts, the asset is written down to the estimated fair value and any resulting impairment loss is reflected on the Consolidated Statements of Operations. As substantially all property, plant and equipment was used in regulated businesses as of December 31 , 2016 , the impacts of regulation are considered when evaluating the carrying value of regulated assets. Income Taxes Berkshire Hathaway includes Nevada Power in its United States federal income tax return. Consistent with established regulatory practice, Nevada Power 's provision for income taxes has been computed on a separate return basis. Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of other comprehensive income ("OCI") are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with income tax benefits and expense for certain property‑related basis differences and other various differences that Nevada Power is required to pass on to its customers are charged or credited directly to a regulatory asset or liability. As of December 31 , 2016 and 2015 , these amounts were recognized as regulatory assets of $141 million and $149 million , respectively, and regulatory liabilities of $9 million and $10 million , respectively , and will be included in regulated rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Valuation allowances are established when necessary to reduce deferred income tax assets to the amount that is more-likely-than-not to be realized. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties. In determining Nevada Power 's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by Nevada Power 's various regulatory jurisdictions. Nevada Power 's income tax returns are subject to continuous examinations by federal, state and local income tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. Nevada Power recognizes the tax benefit from an uncertain tax position only if it is more-likely-than-not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Consolidated Financial Statements from such a position are measured based on the largest benefit that is more-likely-than-not to be realized upon ultimate settlement. Although the ultimate resolution of Nevada Power 's federal, state and local income tax examinations is uncertain, Nevada Power believes it has made adequate provisions for these income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on Nevada Power 's consolidated financial results. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Consolidated Statements of Operations. Revenue Recognition Revenue is recognized as electricity is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31 , 2016 and 2015 , unbilled revenue was $91 million and $116 million , respectively, and is included in accounts receivable, net on the Consolidated Balance Sheets. Rates are established by regulators or contractual arrangements. When preliminary rates are permitted to be billed prior to final approval by the applicable regulator, certain revenue collected may be subject to refund and a liability for estimated refunds is accrued. Nevada Power records sales, franchise and excise taxes collected directly from customers and remitted directly to the taxing authorities on a net basis on the Consolidated Statements of Operations. Nevada Power primarily buys energy and natural gas to satisfy its customer load requirements. Due to changes in retail customer load requirements, Nevada Power may not take physical delivery of the energy or natural gas. Nevada Power may sell the excess energy or natural gas to the wholesale market. In such instances, it is Nevada Power 's policy to record such sales net in cost of fuel, energy and capacity. Unamortized Debt Premiums, Discounts and Issuance Costs Premiums, discounts and financing costs incurred for the issuance of long-term debt are amortized over the term of the related financing on a straight-line basis. Segment Information Nevada Power currently has one segment, which includes its regulated electric utility operations. New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. Nevada Power currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what Nevada Power has the right to invoice as it corresponds directly with the value to the customer of Nevada Power’s performance to date. Nevada Power's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by customer class.
Sierra Pacific Power Company [Member]
Allowance for Doubtful Accounts [Line Items]
Summary of Significant Accounting Policies [Text Block]	Summary of Significant Accounting Policies Basis of Consolidation and Presentation The Consolidated Financial Statements include the accounts of Sierra Pacific and its subsidiaries in which it holds a controlling financial interest as of the financial statement date. Intercompany accounts and transactions have been eliminated. The Consolidated Statements of Comprehensive Income have been omitted as net income equals comprehensive income for the years ended December 31, 2016 , 2015 and 2014 . Certain amounts in the prior period Consolidated Financial Statements have been reclassified to conform to the current period presentation. Such reclassifications did not impact previously reported operating income, net income or retained earnings. Use of Estimates in Preparation of Financial Statements The preparation of the Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; recovery of long-lived assets; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Consolidated Financial Statements. Accounting for the Effects of Certain Types of Regulation Sierra Pacific prepares its Consolidated Financial Statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, Sierra Pacific defers the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future regulated rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in regulated rates occur. Sierra Pacific continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future regulated rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition that could limit Sierra Pacific 's ability to recover its costs. Sierra Pacific believes the application of the guidance for regulated operations is appropriate and its existing regulatory assets and liabilities are probable of inclusion in future regulated rates. The evaluation reflects the current political and regulatory climate at both the federal and state levels. If it becomes no longer probable that the deferred costs or income will be included in future regulated rates, the related regulatory assets and liabilities will be written off to net income, returned to customers or re-established as accumulated other comprehensive income (loss). Fair Value Measurements As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange. Cash Equivalents and Restricted Cash and Investments Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other assets and other current assets on the Consolidated Balance Sheets. Allowance for Doubtful Accounts Accounts receivable are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on Sierra Pacific 's assessment of the collectibility of amounts owed to Sierra Pacific by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. Sierra Pacific also has the ability to assess deposits on customers who have delayed payments or who are deemed to be a credit risk. The change in the balance of the allowance for doubtful accounts, which is included in accounts receivable, net on the Consolidated Balance Sheets, is summarized as follows for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 1 $ 2 $ 1 Charged to operating costs and expenses, net 2 1 2 Write-offs, net (1 ) (2 ) (1 ) Ending balance $ 2 $ 1 $ 2 Derivatives Sierra Pacific employs a number of different derivative contracts, which may include forwards, futures, options, swaps and other agreements, to manage its commodity price and interest rate risk. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked‑to‑market and settled amounts are recognized as cost of fuel, energy and capacity or natural gas purchased for resale on the Consolidated Statements of Operations. For Sierra Pacific 's derivative contracts, the settled amount is generally included in regulated rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in regulated rates are recorded as regulatory assets and liabilities. For a derivative contract not probable of inclusion in rates, changes in the fair value are recognized in earnings. Inventories Inventories consist mainly of materials and supplies totaling $36 million and $34 million as of December 31 , 2016 and 2015 , respectively, and fuel, which includes coal stock, stored natural gas and fuel oil, totaling $9 million and $5 million as of December 31 , 2016 and 2015 , respectively. The cost is determined using the average cost method. Materials are charged to inventory when purchased and are expensed or capitalized to construction work in process, as appropriate, when used. Fuel costs are recovered from retail customers through the base tariff energy rates and deferred energy accounting adjustment charges approved by the Public Utilities Commission of Nevada ("PUCN"). Property, Plant and Equipment, Net General Additions to property, plant and equipment are recorded at cost. Sierra Pacific capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs. Indirect construction costs include debt allowance for funds used during construction ("AFUDC"), and equity AFUDC, as applicable. The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. The cost of repairs and minor replacements are charged to expense when incurred with the exception of costs for generation plant maintenance under certain long-term service agreements. Costs under these agreements are expensed straight-line over the term of the agreements as approved by the PUCN. Depreciation and amortization are generally computed by applying the composite or straight-line method based on either estimated useful lives or mandated recovery periods as prescribed by Sierra Pacific 's various regulatory authorities. Depreciation studies are completed by Sierra Pacific to determine the appropriate group lives, net salvage and group depreciation rates. These studies are reviewed and rates are ultimately approved by the applicable regulatory commission. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as a non-current regulatory liability on the Consolidated Balance Sheets. As actual removal costs are incurred, the associated liability is reduced. Generally when Sierra Pacific retires or sells a component of regulated property, plant and equipment depreciated using the composite method, it charges the original cost, net of any proceeds from the disposition, to accumulated depreciation. Any gain or loss on disposals of all other assets is recorded through earnings with the exception of material gains or losses on regulated property, plant and equipment depreciated on a straight-line basis, which is then recorded to a regulatory asset or liability. Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of regulated facilities, are capitalized as a component of property, plant and equipment, with offsetting credits to the Consolidated Statements of Operations. The rate applied to construction costs is the lower of the PUCN allowed rate of return and rates computed based on guidelines set forth by the Federal Energy Regulatory Commission ("FERC"). After construction is completed, Sierra Pacific is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets. Sierra Pacific 's AFUDC rate used during 2016 and 2015 was 7.62% for electric, 6.02% and 5.97% for natural gas, respectively, and 7.44% for common facilities. Asset Retirement Obligations Sierra Pacific recognizes AROs when it has a legal obligation to perform decommissioning, reclamation or removal activities upon retirement of an asset. Sierra Pacific 's AROs are primarily associated with its generating facilities. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to property, plant and equipment, net) and for accretion of the ARO liability due to the passage of time. The difference between the ARO liability, the corresponding ARO asset included in property, plant and equipment, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability on the Consolidated Balance Sheets. The costs are not recovered in rates until the work has been completed. Impairment of Long-Lived Assets Sierra Pacific evaluates long-lived assets for impairment, including property, plant and equipment, when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable or the assets are being held for sale. Upon the occurrence of a triggering event, the asset is reviewed to assess whether the estimated cash flows expected from the use of the asset plus the residual value from the ultimate disposal exceeds the carrying value of the asset. If the carrying value exceeds the estimated recoverable amounts, the asset is written down to the estimated fair value and any resulting impairment loss is reflected on the Consolidated Statements of Operations. As substantially all property, plant and equipment was used in regulated businesses as of December 31 , 2016 , the impacts of regulation are considered when evaluating the carrying value of regulated assets. Income Taxes Berkshire Hathaway includes Sierra Pacific in its United States federal income tax return. Consistent with established regulatory practice, Sierra Pacific 's provision for income taxes has been computed on a separate return basis. Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of other comprehensive income ("OCI") are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with income tax benefits and expense for certain property-related basis differences and other various differences that Sierra Pacific is required to pass on to its customers are charged or credited directly to a regulatory asset or liability. As of December 31 , 2016 and 2015 , these amounts were recognized as regulatory assets of $85 million and $90 million , respectively, and regulatory liabilities of $6 million and $7 million , respectively , and will be included in regulated rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Valuation allowances are established when necessary to reduce deferred income tax assets to the amount that is more-likely-than-not to be realized. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties. In determining Sierra Pacific 's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by Sierra Pacific 's various regulatory jurisdictions. Sierra Pacific 's income tax returns are subject to continuous examinations by federal, state and local income tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. Sierra Pacific recognizes the tax benefit from an uncertain tax position only if it is more-likely-than-not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Consolidated Financial Statements from such a position are measured based on the largest benefit that is more-likely-than-not to be realized upon ultimate settlement. Although the ultimate resolution of Sierra Pacific 's federal, state and local income tax examinations is uncertain, Sierra Pacific believes it has made adequate provisions for these income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on Sierra Pacific 's consolidated financial results. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Consolidated Statements of Operations. Revenue Recognition Revenue is recognized as electricity or natural gas is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31 , 2016 and 2015 , unbilled revenue was $52 million and $59 million , respectively, and is included in accounts receivable, net on the Consolidated Balance Sheets. Rates are established by regulators or contractual arrangements. When preliminary rates are permitted to be billed prior to final approval by the applicable regulator, certain revenue collected may be subject to refund and a liability for estimated refunds is accrued. Sierra Pacific records sales, franchise and excise taxes collected directly from customers and remitted directly to the taxing authorities on a net basis on the Consolidated Statements of Operations. Sierra Pacific primarily buys energy and natural gas to satisfy its customer load requirements. Due to changes in retail customer load requirements, Sierra Pacific may not take physical delivery of the energy or natural gas. Sierra Pacific may sell the excess energy or natural gas to the wholesale market. In such instances, it is Sierra Pacific 's policy to allocate the natural gas sales between generation and natural gas retail based on usage. The energy sales and natural gas sales allocated to generation are recorded net in cost of fuel, energy and capacity. The natural gas sales allocated to natural gas retail is recorded as wholesale revenue. Unamortized Debt Premiums, Discounts and Issuance Costs Premiums, discounts and financing costs incurred for the issuance of long-term debt are amortized over the term of the related financing on a straight-line basis. New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. Sierra Pacific currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what Sierra Pacific has the right to invoice as it corresponds directly with the value to the customer of Sierra Pacific’s performance to date. Sierra Pacific's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by segment and customer class.

Business Acquisitions (Notes)

Business Acquisitions (Notes)	12 Months Ended
	Dec. 31, 2016
Business Acquisition [Line Items]
Business Acquisitions [Text Block]	Business Acquisitions BHE owns a highly diversified portfolio of businesses comprised primarily of regulated utilities. Consistent with BHE 's strategy to grow and further diversify through a disciplined acquisition approach, the Company closed on several acquisitions during 2016 , 2015 and 2014 . AltaLink Transaction Description On December 1, 2014, BHE completed its acquisition of AltaLink and AltaLink became an indirect wholly owned subsidiary of BHE ("AltaLink Transaction"). Under the terms of the Share Purchase Agreement, dated May 1, 2014, among BHE and SNC-Lavalin Group Inc. ("SNC-Lavalin"), BHE paid C$3.1 billion (US $2.7 billion ) in cash to SNC-Lavalin for 100% of the equity interests of AltaLink. BHE funded the total purchase price with $1.5 billion of junior subordinated debentures issued and sold to subsidiaries of Berkshire Hathaway, $1.0 billion borrowed under its commercial paper program and cash on hand. ALP is a regulated electric transmission business, headquartered in Calgary, Alberta. ALP owns 8,200 miles of transmission lines and 300 substations in Alberta and operates under a cost-of-service regulatory model, including a forward test year, overseen by the Alberta Utilities Commission ("AUC"). Included in BHE's Consolidated Statement of Operations within the BHE Transmission reportable segment for the year ended December 31, 2014 is $13 million of net income as a result of including AltaLink's revenue and expenses from December 1, 2014. Additionally, BHE incurred $3 million of direct transaction costs associated with the AltaLink Transaction that are included in operating expense on the Consolidated Statement of Operations for the year ended December 31, 2014. Pro Forma Financial Information The following unaudited pro forma financial information reflects the consolidated results of operations of BHE, non-recurring transaction costs incurred by both BHE and AltaLink during 2014 and the amortization of the purchase price adjustments each assuming the acquisition had taken place on January 1, 2013 (in millions): 2014 Operating revenue 17,888 Net income attributable to BHE shareholders 2,155 The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of BHE. Other In 2016, the Company completed various other acquisitions totaling $66 million . The purchase prices were allocated to the assets acquired and liabilities assumed in each acquisition. The assets acquired consisted of property, plant and equipment, development and construction costs for renewable projects, other working capital items, goodwill of $50 million and other identifiable intangible assets. The liabilities assumed totaled $54 million . In 2015, the Company completed various other acquisitions totaling $164 million . The purchase prices were allocated to the assets acquired and liabilities assumed in each acquisition. The assets acquired consisted of property, plant and equipment, development and construction costs for renewable projects, other working capital items, goodwill of $33 million and other identifiable intangible assets. The liabilities assumed totaled $84 million . In 2014, the Company completed various other acquisitions totaling $243 million . The purchase price for each acquisition was allocated to the assets acquired and liabilities assumed, which related primarily to property, plant and equipment of $641 million , goodwill of $80 million , long-term debt of $231 million and noncurrent deferred income tax liabilities of $170 million for the remaining 50% interest in CE Generation, LLC ("CE Generation"), development and construction costs for the 300-megawatt ("MW") TX Jumbo Road Wind, LLC wind-powered generation project ("Jumbo Road Project") and real estate brokerage and mortgage businesses. There were no other material assets acquired or liabilities assumed.

Property, Plant and Equipment,

Property, Plant and Equipment, Net (Notes)	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net [Text Block]	Property, Plant and Equipment, Net Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Regulated assets: Utility generation, transmission and distribution systems 5-80 years $ 71,536 $ 69,248 Interstate natural gas pipeline assets 3-80 years 6,942 6,755 78,478 76,003 Accumulated depreciation and amortization (23,603 ) (22,682 ) Regulated assets, net 54,875 53,321 Nonregulated assets: Independent power plants 5-30 years 5,594 4,751 Other assets 3-30 years 1,002 875 6,596 5,626 Accumulated depreciation and amortization (1,060 ) (805 ) Nonregulated assets, net 5,536 4,821 Net operating assets 60,411 58,142 Construction work-in-progress 2,098 2,627 Property, plant and equipment, net $ 62,509 $ 60,769 Construction work-in-progress includes $1.8 billion and $2.3 billion as of December 31, 2016 and 2015 , respectively, related to the construction of regulated assets. During the fourth quarter of 2016, MidAmerican Energy revised its electric and gas depreciation rates based on the results of a new depreciation study, the most significant impact of which was longer estimated useful lives for certain wind-powered generating facilities. The effect of this change was to reduce depreciation and amortization expense by $3 million in 2016 and $34 million annually based on depreciable plant balances at the time of the change.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net [Text Block]	Property, Plant and Equipment, Net Refer to Note 4 of MidAmerican Energy's Notes to Financial Statements. In addition to MidAmerican Energy's property, plant and equipment, net, MidAmerican Funding had nonregulated property gross of $22 million as of December 31, 2016 and 2015 , related accumulated depreciation and amortization of $9 million and $8 million as of December 31, 2016 and 2015 , respectively, and construction work-in-progress of $1 million as of December 31, 2016, which consisted primarily of a corporate aircraft owned by MHC.
MidAmerican Energy Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net [Text Block]	Property, Plant and Equipment, Net Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Utility plant in service: Generation 20-70 years $ 11,282 $ 10,404 Transmission 52-75 years 1,726 1,305 Electric distribution 20-75 years 3,197 3,059 Gas distribution 28-70 years 1,565 1,507 Utility plant in service 17,770 16,275 Accumulated depreciation and amortization (5,448 ) (5,229 ) Utility plant in service, net 12,322 11,046 Nonregulated property, net: Nonregulated property gross 20-50 years 7 15 Accumulated depreciation and amortization (1 ) (5 ) Nonregulated property, net 6 10 12,328 11,056 Construction work-in-progress 493 667 Property, plant and equipment, net $ 12,821 $ 11,723 Nonregulated property includes land, computer software and other assets not recoverable for regulated utility purposes. Computer software reflected in nonregulated property for 2015 was transferred to a subsidiary of BHE on January 1, 2016. The average depreciation and amortization rates applied to depreciable utility plant for the years ended December 31 were as follows: 2016 2015 2014 Electric 2.8 % 3.0 % 2.8 % Gas 2.9 % 2.9 % 2.8 % During the fourth quarter of 2016, MidAmerican Energy revised its electric and gas depreciation rates based on the results of a new depreciation study, the most significant impact of which was longer estimated useful lives for certain wind-powered generating facilities. The effect of this change was to reduce depreciation and amortization expense by $3 million in 2016 and $34 million annually based on depreciable plant balances at the time of the change.
PacifiCorp [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net [Text Block]	Property, Plant and Equipment, Net Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Property, plant and equipment: Generation 14 - 67 years $ 12,371 $ 12,164 Transmission 58 - 75 years 6,055 5,914 Distribution 20 - 70 years 6,590 6,408 Intangible plant (1) 5 - 62 years 884 875 Other 5 - 60 years 1,398 1,396 Property, plant and equipment in-service 27,298 26,757 Accumulated depreciation and amortization (8,793 ) (8,360 ) Net property, plant and equipment in-service 18,505 18,397 Construction work-in-progress 657 629 Total property, plant and equipment, net $ 19,162 $ 19,026 (1) Computer software costs included in intangible plant are initially assigned a depreciable life of 5 to 10 years. The average depreciation and amortization rate applied to depreciable property, plant and equipment was 2.9% , 2.9% and 3.0% for the years ended December 31, 2016 , 2015 and 2014 , respectively. Unallocated Acquisition Adjustments PacifiCorp has unallocated acquisition adjustments that represent the excess of costs of the acquired interests in property, plant and equipment purchased from the entity that first devoted the assets to utility service over their net book value in those assets. These unallocated acquisition adjustments included in other property, plant and equipment had an original cost of $156 million and $155 million as of December 31, 2016 and 2015 , respectively, and accumulated depreciation of $117 million and $112 million as of December 31, 2016 and 2015 , respectively.
Nevada Power Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net [Text Block]	Property, Plant and Equipment, Net Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Utility plant: Generation 30 - 55 years $ 4,271 $ 4,212 Distribution 20 - 65 years 3,231 3,118 Transmission 45 - 65 years 1,846 1,788 General and intangible plant 5 - 65 years 738 694 Utility plant 10,086 9,812 Accumulated depreciation and amortization (3,205 ) (2,971 ) Utility plant, net 6,881 6,841 Other non-regulated, net of accumulated depreciation and amortization 45 years 2 2 Plant, net 6,883 6,843 Construction work-in-progress 114 153 Property, plant and equipment, net $ 6,997 $ 6,996 Almost all of Nevada Power 's plant is subject to the ratemaking jurisdiction of the PUCN and the FERC. Nevada Power 's depreciation and amortization expense, as authorized by the PUCN, stated as a percentage of the depreciable property balances as of December 31 , 2016 , 2015 and 2014 was 3.2% , 3.0% and 3.3% , respectively. Nevada Power is required to file a utility plant depreciation study every six years as a companion filing with the triennial general rate case filings. Construction work-in-progress is related to the construction of regulated assets.
Sierra Pacific Power Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net [Text Block]	Property, Plant and Equipment, Net Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Utility plant: Electric generation 30 - 60 years $ 1,137 $ 1,134 Electric distribution 20 - 70 years 1,417 1,382 Electric transmission 50 - 70 years 771 739 Electric general and intangible plant 5 - 65 years 164 139 Natural gas distribution 40 - 70 years 381 374 Natural gas general and intangible plant 5 - 60 years 15 13 Common general 5 - 65 years 267 265 Utility plant 4,152 4,046 Accumulated depreciation and amortization (1,442 ) (1,368 ) Utility plant, net 2,710 2,678 Other non-regulated, net of accumulated depreciation and amortization 60 years 5 — Plant, net 2,715 2,678 Construction work-in-progress 107 88 Property, plant and equipment, net $ 2,822 $ 2,766 All of Sierra Pacific 's plant is subject to the ratemaking jurisdiction of the PUCN and the FERC. Sierra Pacific 's depreciation and amortization expense, as authorized by the PUCN, stated as a percentage of the depreciable property balances as of December 31 , 2016 , 2015 and 2014 was 3.0% , 2.9% and 3.0% , respectively. Sierra Pacific is required to file a utility plant depreciation study every six years as a companion filing with the triennial general rate case filings. Construction work-in-progress is related to the construction of regulated assets. During 2016, Sierra Pacific revised its electric and gas depreciation rates based on the results of a new depreciation study, the most significant impact of which was shorter estimated useful lives at the Valmy Generating Station. The effect of this change will increase depreciation and amortization expense by $9 million annually based on depreciable plant balances at the time of the change. However, the PUCN ordered the change relating to the Valmy Generating Station of $7 million annually be deferred for future recovery through a regulatory asset.

Jointly Owned Utility Facilitie

Jointly Owned Utility Facilities (Notes)	12 Months Ended
	Dec. 31, 2016
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Text Block]	Jointly Owned Utility Facilities Under joint facility ownership agreements, the Domestic Regulated Businesses, as tenants in common, have undivided interests in jointly owned generation, transmission, distribution and pipeline common facilities. The Company accounts for its proportionate share of each facility, and each joint owner has provided financing for its share of each facility. Operating costs of each facility are assigned to joint owners based on their percentage of ownership or energy production, depending on the nature of the cost. Operating costs and expenses on the Consolidated Statements of Operations include the Company's share of the expenses of these facilities. The amounts shown in the table below represent the Company's share in each jointly owned facility as of December 31, 2016 (dollars in millions): Accumulated Construction Company Facility In Depreciation and Work-in- Share Service Amortization Progress PacifiCorp: Jim Bridger Nos. 1-4 67 % $ 1,420 $ 583 $ 10 Hunter No. 1 94 473 161 1 Hunter No. 2 60 296 98 — Wyodak 80 467 203 1 Colstrip Nos. 3 and 4 10 244 130 5 Hermiston 50 178 76 2 Craig Nos. 1 and 2 19 325 223 32 Hayden No. 1 25 74 32 — Hayden No. 2 13 43 20 — Foote Creek 79 39 25 — Transmission and distribution facilities Various 777 228 61 Total PacifiCorp 4,336 1,779 112 MidAmerican Energy: Louisa No. 1 88 % 766 418 9 Quad Cities Nos. 1 and 2 (1) 25 689 367 7 Walter Scott, Jr. No. 3 79 614 303 1 Walter Scott, Jr. No. 4 (2) 60 448 101 2 George Neal No. 4 41 307 154 1 Ottumwa No. 1 52 548 191 13 George Neal No. 3 72 426 174 1 Transmission facilities Various 247 86 1 Total MidAmerican Energy 4,045 1,794 35 NV Energy: Navajo 11 % 213 145 2 Silverhawk 75 248 66 3 Valmy 50 389 216 1 Transmission facilities Various 213 41 — Total NV Energy 1,063 468 6 BHE Pipeline Group - common facilities Various 286 164 — Total $ 9,730 $ 4,205 $ 153 (1) Includes amounts related to nuclear fuel. (2) Facility in-service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling $319 million and $75 million , respectively.
PacifiCorp [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Text Block]	Jointly Owned Utility Facilities Under joint facility ownership agreements with other utilities, PacifiCorp, as a tenant in common, has undivided interests in jointly owned generation, transmission and distribution facilities. PacifiCorp accounts for its proportionate share of each facility, and each joint owner has provided financing for its share of each facility. Operating costs of each facility are assigned to joint owners based on their percentage of ownership or energy production, depending on the nature of the cost. Operating costs and expenses on the Consolidated Statements of Operations include PacifiCorp's share of the expenses of these facilities. The amounts shown in the table below represent PacifiCorp's share in each jointly owned facility as of December 31, 2016 (dollars in millions): Facility Accumulated Construction PacifiCorp in Depreciation and Work-in- Share Service Amortization Progress Jim Bridger Nos. 1 - 4 67 % $ 1,420 $ 583 $ 10 Hunter No. 1 94 473 161 1 Hunter No. 2 60 296 98 — Wyodak 80 467 203 1 Colstrip Nos. 3 and 4 10 244 130 5 Hermiston 50 178 76 2 Craig Nos. 1 and 2 19 325 223 32 Hayden No. 1 25 74 32 — Hayden No. 2 13 43 20 — Foote Creek 79 39 25 — Transmission and distribution facilities Various 777 228 61 Total $ 4,336 $ 1,779 $ 112
MidAmerican Energy Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Text Block]	Jointly Owned Utility Facilities Under joint facility ownership agreements with other utilities, MidAmerican Energy, as a tenant in common, has undivided interests in jointly owned generation and transmission facilities. MidAmerican Energy accounts for its proportionate share of each facility, and each joint owner has provided financing for its share of each facility. Operating costs of each facility are assigned to joint owners based on their percentage of ownership or energy production, depending on the nature of the cost. Operating costs and expenses on the Statements of Operations include MidAmerican Energy's share of the expenses of these facilities. The amounts shown in the table below represent MidAmerican Energy's share in each jointly owned facility as of December 31, 2016 (dollars in millions): Accumulated Construction Company Plant in Depreciation and Work-in- Share Service Amortization Progress Louisa Unit No. 1 88.0 % $ 766 $ 418 $ 9 Quad Cities Unit Nos. 1 & 2 (1) 25.0 689 367 7 Walter Scott, Jr. Unit No. 3 79.1 614 303 1 Walter Scott, Jr. Unit No. 4 (2) 59.7 448 101 2 George Neal Unit No. 4 40.6 307 154 1 Ottumwa Unit No. 1 52.0 548 191 13 George Neal Unit No. 3 72.0 426 174 1 Transmission facilities (3) Various 247 86 1 Total $ 4,045 $ 1,794 $ 35 (1) Includes amounts related to nuclear fuel. (2) Plant in service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling $319 million and $75 million , respectively. (3) Includes 345 and 161 kilovolt transmission lines and substations.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Text Block]	Jointly Owned Utility Facilities Refer to Note 5 of MidAmerican Energy's Notes to Financial Statements.
Nevada Power Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Text Block]	Jointly Owned Utility Facilities Under joint facility ownership agreements, Nevada Power , as tenants in common, has undivided interests in jointly owned generation and transmission facilities. Nevada Power accounts for its proportionate share of each facility and each joint owner has provided financing for its share of each facility. Operating costs of each facility are assigned to joint owners based on their percentage of ownership or energy production, depending on the nature of the cost. Operating costs and expenses on the Consolidated Statements of Operations include Nevada Power 's share of the expenses of these facilities. The amounts shown in the table below represent Nevada Power 's share in each jointly owned facility as of December 31 , 2016 (dollars in millions): Nevada Construction Power's Utility Accumulated Work-in- Share Plant Depreciation Progress Silverhawk Generating Station 75 % $ 248 $ 66 $ 3 Navajo Generating Station 11 213 145 2 ON Line Transmission Line 24 145 12 — Other Transmission Facilities Various 56 26 — Total $ 662 $ 249 $ 5
Sierra Pacific Power Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Text Block]	Jointly Owned Utility Facilities Under joint facility ownership agreements, Sierra Pacific , as tenants in common, has undivided interests in jointly owned generation and transmission facilities. Sierra Pacific accounts for its proportionate share of each facility and each joint owner has provided financing for its share of each facility. Operating costs of each facility are assigned to joint owners based on their percentage of ownership or energy production, depending on the nature of the cost. Operating costs and expenses on the Consolidated Statements of Operations include Sierra Pacific 's share of the expenses of these facilities. The amounts shown in the table below represent Sierra Pacific 's share in each jointly owned facility as of December 31 , 2016 (dollars in millions): Sierra Construction Pacific's Utility Accumulated Work-in- Share Plant Depreciation Progress Valmy Generating Station 50 % $ 389 $ 216 $ 1 ON Line Transmission Line 1 8 1 — Valmy Transmission 50 4 2 — Total $ 401 $ 219 $ 1

Regulatory Matters (Notes)

Regulatory Matters (Notes)	12 Months Ended
	Dec. 31, 2016
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Matters [Text Block]	Regulatory Matters Regulatory Assets Regulatory assets represent costs that are expected to be recovered in future regulated rates. The Company's regulatory assets reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Deferred income taxes (1) 27 years $ 1,754 $ 1,577 Employee benefit plans (2) 17 years 816 778 Asset disposition costs Various 281 307 Deferred net power costs 1 year 38 140 Asset retirement obligations 12 years 301 281 Unrealized loss on regulated derivative contracts 5 years 154 250 Abandoned projects 3 years 159 136 Unamortized contract values 7 years 98 110 Other Various 856 706 Total regulatory assets $ 4,457 $ 4,285 Reflected as: Current assets $ 150 $ 130 Noncurrent assets 4,307 4,155 Total regulatory assets $ 4,457 $ 4,285 (1) Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse. (2) Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized. The Company had regulatory assets not earning a return on investment of $2.8 billion and $2.3 billion as of December 31, 2016 and 2015 , respectively. Regulatory Liabilities Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. The Company's regulatory liabilities reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Cost of removal (1) 27 years $ 2,242 $ 2,167 Deferred net power costs 1 years 64 206 Asset retirement obligations 35 years 122 147 Levelized depreciation 23 years 244 199 Impact fees 6 years 90 — Employee benefit plans (2) 12 years 25 13 Unrealized gain on regulated derivative contracts 1 year 6 — Other Various 327 301 Total regulatory liabilities $ 3,120 $ 3,033 Reflected as: Current liabilities $ 187 $ 402 Noncurrent liabilities 2,933 2,631 Total regulatory liabilities $ 3,120 $ 3,033 (1) Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost. (2) Represents amounts not yet recognized as a component of net periodic benefit cost that are to be returned to customers in future periods when recognized. ALP General Tariff Application ("GTA") In November 2014, ALP filed a GTA requesting the Alberta Utilities Commission ("AUC") to approve revenue requirements of C$811 million for 2015 and C$1.0 billion for 2016, primarily due to continued investment in capital projects as directed by the Alberta Electric System Operator. ALP amended the GTA in June 2015 to propose transmission tariff relief measures for customers and modifications to its capital structure. ALP also amended and updated the GTA in October 2015, reducing the requested revenue requirements to C$672 million for 2015 and C$704 million for 2016. In May 2016, the AUC issued its decision pertaining to the 2015-2016 GTA. ALP filed its 2015-2016 GTA compliance filing in July 2016 to comply with the AUC's decision. The compliance filing requested the AUC to approve revenue requirements of C$599 million for 2015 and C$685 million for 2016. The decreased revenue requirements requested in the compliance filing, as compared to the 2015-2016 GTA filing updated in October 2015, were primarily due to the AUC approval of ALP's proposed immediate tariff relief of C$415 million for customers for 2015 and 2016, through (i) the discontinuance of construction work-in-progress ("CWIP") in rate base and the return to allowance for funds used during construction ("AFUDC") accounting effective January 1, 2015, resulting in a C$82 million reduction of revenue requirement and the refund of C$277 million previously collected as CWIP in rate base as part of ALP's transmission tariffs during 2011-2014 less related returns of C$12 million and (ii) a change to the flow through method for calculating income taxes for 2016, resulting in further tariff relief of C$68 million . Operating revenue for the year ended December 31, 2016 , included a one-time reduction of $200 million from the 2015-2016 GTA decision received in May 2016 at ALP. The 2015-2016 GTA decision required ALP to refund $200 million to customers in 2016 through reduced monthly billings for the change from receiving cash during construction for the return on CWIP in rate base to recording allowance for borrowed and equity funds used during construction related to construction expenditures during the 2011 to 2014 time period. This amount is offset with higher capitalized interest and allowance for equity funds in the Consolidated Statements of Operations. In addition, the decision required ALP to change to the flow through method of recognizing income tax expense effective January 1, 2016. This change reduced operating revenue by $45 million for the year ended December 31, 2016 , with offsetting impacts to income tax expense in the Consolidated Statements of Operations.
PacifiCorp [Member]
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Matters [Text Block]	Regulatory Matters Regulatory Assets Regulatory assets represent costs that are expected to be recovered in future rates. PacifiCorp's regulatory assets reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Deferred income taxes (1) 26 years $ 421 $ 437 Employee benefit plans (2) 21 years 525 499 Utah mine disposition (3) Various 166 186 Unamortized contract values 7 years 98 110 Deferred net power costs 1 year 33 86 Unrealized loss on derivative contracts 5 years 73 133 Asset retirement obligation 20 years 82 65 Other Various 145 169 Total regulatory assets $ 1,543 $ 1,685 Reflected as: Current assets $ 53 $ 102 Noncurrent assets 1,490 1,583 Total regulatory assets $ 1,543 $ 1,685 (1) Amounts primarily represent income tax benefits and expense related to certain property-related basis differences and other various items that PacifiCorp is required to pass on to its customers. (2) Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in rates when recognized. (3) Amounts represent regulatory assets established as a result of the Utah mine disposition discussed below for the net property, plant and equipment not considered probable of disallowance and for the portion of losses associated with the assets held for sale, UMWA 1974 Pension Plan withdrawal and closure costs incurred to date considered probable of recovery. PacifiCorp had regulatory assets not earning a return on investment of $1.019 billion and $1.102 billion as of December 31 , 2016 and 2015 , respectively. Regulatory Liabilities Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. PacifiCorp's regulatory liabilities reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Cost of removal (1) 26 years $ 917 $ 894 Deferred income taxes Various 9 12 Other Various 106 66 Total regulatory liabilities $ 1,032 $ 972 Reflected as: Current liabilities $ 54 $ 34 Noncurrent liabilities 978 938 Total regulatory liabilities $ 1,032 $ 972 (1) Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost. Utah Mine Disposition In December 2014, PacifiCorp filed applications with the Utah Public Service Commission ("UPSC"), the Oregon Public Utility Commission ("OPUC"), the Wyoming Public Service Commission ("WPSC") and the Idaho Public Utilities Commission ("IPUC") seeking certain approvals, prudence determinations and accounting orders to close its Deer Creek mining operations, sell certain Utah mining assets, enter into a replacement coal supply agreement, amend an existing coal supply agreement, withdraw from the United Mine Workers of America ("UMWA") 1974 Pension Plan and settle PacifiCorp's other postretirement benefit obligation for UMWA participants (collectively, the "Utah Mine Disposition"). In 2015, PacifiCorp received approval from the commissions. In December 2014, PacifiCorp filed an advice letter with the California Public Utility Commission (" CPUC ") to request approval to sell certain Utah mining assets and to establish memorandum accounts to track the costs associated with the Utah Mine Disposition for future recovery. In July 2015, the CPUC Energy Division issued a letter requiring PacifiCorp to file a formal application for approval of the sale of certain Utah mining assets. Accordingly, in September 2015, PacifiCorp filed an application with the CPUC . On February 6, 2017, a joint motion was filed with the CPUC seeking approval of a settlement agreement reached by PacifiCorp and all other parties. The agreement states, among other things, that the decision to sell certain Utah mining assets is in the public interest. Parties also reserve their rights to additional testimony, briefs, and hearings to the extent the CPUC determines that additional California Environmental Quality Act proceedings are necessary. A CPUC decision on the joint motion and settlement agreement is expected in 2017.
MidAmerican Energy Company [Member]
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Matters [Text Block]	Regulatory Matters Regulatory assets represent costs that are expected to be recovered in future regulated rates. MidAmerican Energy's regulatory assets reflected on the Balance Sheets consist of the following as of December 31 (in millions): Average Remaining Life 2016 2015 Deferred income taxes, net (1) 29 years $ 985 $ 858 Asset retirement obligations (2) 9 years 105 94 Employee benefit plans (3) 11 years 40 39 Unrealized loss on regulated derivative contracts 1 year 2 20 Other Various 29 33 Total $ 1,161 $ 1,044 (1) Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse. (2) Amount predominantly relates to asset retirement obligations for fossil-fueled and wind-powered generating facilities. Refer to Note 12 for a discussion of asset retirement obligations. (3) Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized. MidAmerican Energy had regulatory assets not earning a return on investment of $1.2 billion and $1.0 billion as of December 31, 2016 and 2015 , respectively. Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. MidAmerican Energy's regulatory liabilities reflected on the Balance Sheets consist of the following as of December 31 (in millions): Average Remaining Life 2016 2015 Cost of removal accrual (1) 29 years $ 665 $ 653 Asset retirement obligations (2) 36 years 117 140 Pre-funded AFUDC on transmission MVPs (3) 56 years 35 19 Iowa electric revenue sharing accrual (4) 1 year 30 — Employee benefit plans (5) 11 years 12 — Unrealized gain on regulated derivative contracts 1 year 6 — Other Various 18 19 Total $ 883 $ 831 (1) Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing utility plant in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost. (2) Amount predominantly represents the excess of nuclear decommission trust assets over the related asset retirement obligation. Refer to Note 12 for a discussion of asset retirement obligations. (3) Represents AFUDC accrued on transmission MVPs that is deducted from rate base as a result of the inclusion of related construction work-in-progress in rate base. (4) Represents current-year accruals under a regulatory arrangement in Iowa in which equity returns exceeding specified thresholds reduce utility plant upon final determination. (5) Represents amounts not yet recognized as a component of net periodic benefit cost that are to be returned to customers in future periods when recognized.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Matters [Text Block]	Regulatory Matters Refer to Note 6 of MidAmerican Energy's Notes to Financial Statements.
Nevada Power Company [Member]
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Matters [Text Block]	Regulatory Matters Regulatory assets represent costs that are expected to be recovered in future rates. Nevada Power 's regulatory assets reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Deferred income taxes (1) 27 years $ 141 $ 149 Merger costs from 1999 merger 28 years 136 143 Deferred operating costs 20 years 127 87 Decommissioning costs 7 years 114 121 Employee benefit plans (2) 10 years 105 98 Abandoned projects 3 years 75 91 Asset retirement obligations 7 years 74 79 Legacy meters 16 years 60 64 Merrill Lynch deferred energy costs 3 years 40 56 Other Various 148 169 Total regulatory assets $ 1,020 $ 1,057 Reflected as: Current assets $ 20 $ — Other assets 1,000 1,057 Total regulatory assets $ 1,020 $ 1,057 (1) Amounts represent income tax benefits related to accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse. (2) Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized. Nevada Power had regulatory assets not earning a return on investment of $560 million and $572 million as of December 31 , 2016 and 2015 , respectively. The regulatory assets not earning a return on investment primarily consist of deferred income taxes, merger costs from 1999 merger, asset retirement obligations, deferred operating costs, a portion of the employee benefit plans, deferred energy costs and losses on reacquired debt. Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. Nevada Power 's regulatory liabilities reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Cost of removal (1) 33 years $ 294 $ 273 Impact fees 6 years 90 — Energy efficiency program 1 year 37 34 Deferred energy costs 1 year — 139 Other Various 32 31 Total regulatory liabilities $ 453 $ 477 Reflected as: Current liabilities $ 37 $ 173 Other long-term liabilities 416 304 Total regulatory liabilities $ 453 $ 477 (1) Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost. Deferred Energy Nevada statutes permit regulated utilities to adopt deferred energy accounting procedures. The intent of these procedures is to ease the effect on customers of fluctuations in the cost of purchased natural gas, fuel and electricity and are subject to annual prudency review by the PUCN. Under deferred energy accounting, to the extent actual fuel and purchased power costs exceed fuel and purchased power costs recoverable through current rates that excess is not recorded as a current expense on the Consolidated Statements of Operations but rather is deferred and recorded as a regulatory asset on the Consolidated Balance Sheets and would be included in the table above as deferred energy costs. Conversely, a regulatory liability is recorded to the extent fuel and purchased power costs recoverable through current rates exceed actual fuel and purchased power costs and is included in the table above as deferred energy costs. These excess amounts are reflected in quarterly adjustments to rates and recorded as cost of fuel, energy and capacity in future time periods. Energy Efficiency Program Rates ("EEPR") and Energy Efficiency Implementation Rates ("EEIR") EEPR was established to allow Nevada Power to recover the costs of implementing energy efficiency programs and EEIR was established to offset the negative impacts on revenue associated with the successful implementation of energy efficiency programs. These rates change once a year in the utility's annual DEAA application based on energy efficiency program budgets prepared by Nevada Power and approved by the PUCN in integrated resource plan proceedings. To the extent Nevada Power's earned rate of return exceeds the rate of return used to set base general rates, Nevada Power is required to refund to customers EEIR revenue previously collected for that year. In March 2016, Nevada Power filed an application to reset the EEIR and EEPR and refund the EEIR revenue received in 2015, including carrying charges. In July 2016, the PUCN issued an order accepting a stipulation requiring Nevada Power to refund the 2015 revenue and reset the rates as filed effective October 1, 2016. The EEIR liability for Nevada Power is $10 million and $18 million , which is included in current regulatory liabilities on the Consolidated Balance Sheets as of December 31 , 2016 and 2015 , respectively. Chapter 704B Applications In May 2015, three customers, including MGM Resorts International ("MGM") and Wynn Las Vegas, LLC ("Wynn"), filed applications to purchase energy from alternative providers of a new electric resource and become distribution only service customers. In December 2015, the PUCN granted the applications subject to conditions, including paying an impact fee, on-going charges and receiving approval for specific alternative energy providers and terms. The costs associated with the impact fee and on-going charges were assessed to alleviate the burden on other Nevada Power customers for the applicants' share of previously committed investments and long-term renewable contracts. The impact fee is set on a case-by-case basis by the PUCN and at a level designed such that the remaining customers are not subjected to increased costs. In December 2015, the applicants filed petitions for reconsideration. In January 2016, the PUCN granted reconsideration and updated some of the terms, including removing a limitation related to energy purchased indirectly from NV Energy. In June 2016, MGM and Wynn made the required compliance filings and the PUCN issued orders allowing the customers to acquire electric energy and ancillary services from another energy supplier and become distribution only service customers of Nevada Power. The third customer did not proceed with purchasing energy from alternative providers. In September 2016, MGM and Wynn paid impact fees totaling $97 million . In October 2016, MGM and Wynn became distribution only service customers and started procuring energy from another energy supplier. In December 2016, as contemplated in the PUCN order, the impact fees were increased $2 million to reflect final energy costs for MGM and Wynn. In September 2016, Switch, Ltd. ("Switch"), a customer of Nevada Power , filed an application with the PUCN to purchase energy from alternative providers of a new electric resource and become a distribution only service customer of Nevada Power . In December 2016, the PUCN approved a stipulation agreement that allowed Switch to purchase energy from alternative providers subject to conditions, including paying an impact fee in the Nevada Power service territory. Switch has provided notice that it intends to proceed with purchasing energy from alternative providers.
Sierra Pacific Power Company [Member]
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Matters [Text Block]	Regulatory Matters Regulatory assets represent costs that are expected to be recovered in future rates. Sierra Pacific 's regulatory assets reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Employee benefit plans (1) 10 years $ 128 $ 126 Deferred income taxes (2) 27 years 85 90 Merger costs from 1999 merger 30 years 80 83 Abandoned projects 9 years 39 44 Renewable energy programs 1 year 25 — Losses on reacquired debt 17 years 22 22 Other Various 56 67 Total regulatory assets $ 435 $ 432 Reflected as: Current assets $ 25 $ — Other assets 410 432 Total regulatory assets $ 435 $ 432 (1) Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized. (2) Amounts represent income tax benefits related to accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse. Sierra Pacific had regulatory assets not earning a return on investment of $305 million and $254 million as of December 31 , 2016 and 2015 , respectively. The regulatory assets not earning a return on investment primarily consist of deferred income taxes, merger costs from 1999 merger, a portion of the employee benefit plans, losses on reacquired debt, legacy meters, a portion of abandoned projects and asset retirement obligations. Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. Sierra Pacific 's regulatory liabilities reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Cost of removal (1) 39 years $ 205 $ 208 Deferred energy costs 1 year 64 66 Renewable energy program 1 year — 8 Other Various 21 26 Total regulatory liabilities $ 290 $ 308 Reflected as: Current liabilities $ 69 $ 78 Other long-term liabilities 221 230 Total regulatory liabilities $ 290 $ 308 (1) Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost. Deferred Energy Nevada statutes permit regulated utilities to adopt deferred energy accounting procedures. The intent of these procedures is to ease the effect on customers of fluctuations in the cost of purchased natural gas, fuel and electricity and are subject to annual prudency review by the PUCN. Under deferred energy accounting, to the extent actual fuel and purchased power costs exceed fuel and purchased power costs recoverable through current rates that excess is not recorded as a current expense on the Consolidated Statements of Operations but rather is deferred and recorded as a regulatory asset on the Consolidated Balance Sheets and would be included in the table above as deferred energy costs. Conversely, a regulatory liability is recorded to the extent fuel and purchased power costs recoverable through current rates exceed actual fuel and purchased power costs and is included in the table above as deferred energy costs. These excess amounts are reflected in quarterly adjustments to rates and recorded as cost of fuel, energy and capacity in future time periods. General Rate Cases In June 2016, Sierra Pacific filed an electric regulatory rate review with the PUCN. The filing requested no incremental annual revenue relief. In October 2016, Sierra Pacific filed with the PUCN a settlement agreement resolving most, but not all, issues in the proceeding and reduced Sierra Pacific's electric revenue requirement by $3 million spread evenly to all rate classes. In December 2016, the PUCN approved the settlement agreement and established an additional six MW of net metering capacity under the grandfathered rates, which are those net metering rates that were in effect prior to January 2016; the order establishes cost-based rates and a value-based excess energy credit for customers who choose to install private generation after the six MW limitation is reached. The new rates were effective January 1, 2017. In January 2017, Sierra Pacific filed a petition for reconsideration relating to the creation of the additional six MW of net metering at the grandfathered rates. Sierra Pacific believes the effects of the PUCN decision result in additional cost shifting to non-net metering customers and reduces the stipulated rate reduction for other customer classes. In June 2016, Sierra Pacific filed a gas regulatory rate review with the PUCN. The filing requested a slight decrease in its incremental annual revenue requirement. In October 2016, Sierra Pacific filed with the PUCN a settlement agreement resolving all issues in the proceeding and reduced Sierra Pacific's gas revenue requirement by $2 million . In December 2016, the PUCN approved the settlement agreement. The new rates were effective January 1, 2017. Energy Efficiency Program Rates ("EEPR") and Energy Efficiency Implementation Rates ("EEIR") EEPR was established to allow Sierra Pacific to recover the costs of implementing energy efficiency programs and EEIR was established to offset the negative impacts on revenue associated with the successful implementation of energy efficiency programs. These rates change once a year in the utility's annual DEAA application based on energy efficiency program budgets prepared by Sierra Pacific and approved by the PUCN in integrated resource plan proceedings. To the extent Sierra Pacific's earned rate of return exceeds the rate of return used to set base general rates, Sierra Pacific is required to refund to customers EEIR revenue previously collected for that year. In March 2016, Sierra Pacific filed an application to reset the EEIR and EEPR and refund the EEIR revenue received in 2015, including carrying charges. In July 2016, the PUCN issued an order accepting a stipulation requiring Sierra Pacific to refund the 2015 revenue and reset the rates as filed effective October 1, 2016. The EEIR liability for Sierra Pacific is $2 million and $3 million , which is included in current regulatory liabilities on the Consolidated Balance Sheets as of December 31 , 2016 and 2015 , respectively. Chapter 704B Applications In September 2016, Switch, Ltd. ("Switch"), a customer of Sierra Pacific , filed an application with the PUCN to purchase energy from alternative providers of a new electric resource and become a distribution only service customer of Sierra Pacific . In December 2016, the PUCN approved a stipulation agreement that allowed Switch to purchase energy from alternative providers . Switch has provided notice that it intends to proceed with purchasing energy from alternative providers.

Investments and Restricted Cash

Investments and Restricted Cash and Investments (Notes)	12 Months Ended
	Dec. 31, 2016
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Investments and Restricted Cash and Investments [Text Block]	Investments and Restricted Cash and Investments Investments and restricted cash and investments consists of the following as of December 31 (in millions): 2016 2015 Investments: BYD Company Limited common stock $ 1,185 $ 1,238 Rabbi trusts 403 380 Other 106 130 Total investments 1,694 1,748 Equity method investments: Electric Transmission Texas, LLC 672 585 Bridger Coal Company 165 190 BHE Renewables tax equity investments 741 168 Other 142 160 Total equity method investments 1,720 1,103 Restricted cash and investments: Quad Cities Station nuclear decommissioning trust funds 460 429 Solar Star and Topaz Projects 64 95 Other 218 129 Total restricted cash and investments 742 653 Total investments and restricted cash and investments $ 4,156 $ 3,504 Reflected as: Current assets $ 211 $ 137 Noncurrent assets 3,945 3,367 Total investments and restricted cash and investments $ 4,156 $ 3,504 Investments BHE's investment in BYD Company Limited common stock is accounted for as an available-for-sale security with changes in fair value recognized in AOCI. The fair value of BHE's investment in BYD Company Limited common stock reflects a pre-tax unrealized gain of $953 million and $1,006 million as of December 31, 2016 and 2015 , respectively. Rabbi trusts primarily hold corporate-owned life insurance on certain current and former key executives and directors. The Rabbi trusts were established to hold investments used to fund the obligations of various nonqualified executive and director compensation plans and to pay the costs of the trusts. The amount represents the cash surrender value of all of the policies included in the Rabbi trusts, net of amounts borrowed against the cash surrender value. Equity Method Investments BHE , through a subsidiary, owns 50% of Electric Transmission Texas, LLC , which owns and operates electric transmission assets in the Electric Reliability Council of Texas footprint. BHE , through a subsidiary, owns 66.67% of Bridger Coal Company ("Bridger Coal"), which is a coal mining joint venture that supplies coal to the Jim Bridger generating facility. Bridger Coal is being accounted for under the equity method of accounting as the power to direct the activities that most significantly impact Bridger Coal's economic performance are shared with the joint venture partner. The Company has also invested in projects sponsored by third parties, commonly referred to as tax equity investments. Under the terms of these tax equity investments, the Company has entered into equity capital contribution agreements with the project sponsors that require contributions. The Company has made contributions of $170 million in 2015 and $584 million in 2016 pursuant to these equity capital contribution agreements as the various projects achieve commercial operation. Once a project achieves commercial operation, the Company enters into a partnership agreement with the project sponsor that directs and allocates the operating profits and tax benefits from the project. Restricted Cash and Investments MidAmerican Energy has established a trust for the investment of funds for decommissioning the Quad Cities Nuclear Station Units 1 and 2 ("Quad Cities Station"). These investments in debt and equity securities are classified as available-for-sale and are reported at fair value. Funds are invested in the trust in accordance with applicable federal and state investment guidelines and are restricted for use as reimbursement for costs of decommissioning the Quad Cities Station, which are currently licensed for operation until December 2032.
MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Investments and Restricted Cash and Investments [Text Block]	Investments and Restricted Cash and Investments Investments and restricted cash and investments consists of the following amounts as of December 31 (in millions): 2016 2015 Nuclear decommissioning trust $ 460 $ 429 Rabbi trusts 184 175 Auction rate securities — 26 Other 9 4 Total $ 653 $ 634 MidAmerican Energy has established a trust for the investment of funds for decommissioning the Quad Cities Station. These investments in debt and equity securities are classified as available-for-sale and are reported at fair value. Funds are invested in the trust in accordance with applicable federal and state investment guidelines and are restricted for use as reimbursement for costs of decommissioning the Quad Cities Station, which is currently licensed for operation until December 2032. As of December 31, 2016 and 2015 , the fair value of the trust's funds was invested as follows: 54% and 56% , respectively, in domestic common equity securities, 35% and 31% , respectively, in United States government securities, 8% and 9% , respectively, in domestic corporate debt securities and 3% and 4% , respectively, in other securities. Rabbi trusts primarily hold corporate-owned life insurance on certain current and former key executives and directors. The Rabbi trusts were established to hold investments used to fund the obligations of various nonqualified executive and director compensation plans and to pay the costs of the trusts. The amount represents the cash surrender value of all of the policies included in the Rabbi trusts, net of amounts borrowed against the cash surrender value. Changes in the cash surrender value of the policies are reflected in other income and (expense) - other, net on the Statements of Operation. MidAmerican Energy had investments in interest bearing auction rate securities with a par value of $35 million as of December 31, 2015 . MidAmerican Energy considered the securities to be temporarily impaired, except for an other-than-temporary impairment of $3 million , after-tax, recorded in 2008, and had recorded unrealized losses on the securities of $3 million , after tax, in AOCI as of December 31, 2015 . All of the securities were redeemed at par value during 2016, and MidAmerican Energy recorded a $3 million after-tax gain as a result of the previous other-than-temporary impairment.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Investments and Restricted Cash and Investments [Text Block]	Investments and Restricted Cash and Investments Refer to Note 7 of MidAmerican Energy's Notes to Financial Statements in Item 8 of this Form 10-K. In addition to MidAmerican Energy's investments and restricted cash and investments, MHC had corporate-owned life insurance policies in a Rabbi trust owned by MHC with a total cash surrender value of $2 million as of December 31, 2016 and 2015 .

Short-Term Debt and Credit Faci

Short-Term Debt and Credit Facilities (Notes)	12 Months Ended
	Dec. 31, 2016
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Short-Term Debt and Credit Facilities The following table summarizes BHE's and its subsidiaries' availability under their credit facilities as of December 31, (in millions): MidAmerican NV Northern BHE PacifiCorp Funding Energy Powergrid AltaLink Other Total (1) 2016: Credit facilities $ 2,000 $ 1,000 $ 609 $ 650 $ 185 $ 986 $ 915 $ 6,345 Less: Short-term debt (834 ) (270 ) (99 ) — — (289 ) (377 ) (1,869 ) Tax-exempt bond support and letters of credit (7 ) (142 ) (220 ) (80 ) — (8 ) — (457 ) Net credit facilities $ 1,159 $ 588 $ 290 $ 570 $ 185 $ 689 $ 538 $ 4,019 2015: Credit facilities $ 2,000 $ 1,200 $ 609 $ 650 $ 221 $ 813 $ 928 $ 6,421 Less: Short-term debt (253 ) (20 ) — — — (401 ) (300 ) (974 ) Tax-exempt bond support and letters of credit (51 ) (160 ) (195 ) — — (9 ) — (415 ) Net credit facilities $ 1,696 $ 1,020 $ 414 $ 650 $ 221 $ 403 $ 628 $ 5,032 (1) The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method. As of December 31, 2016 , the Company was in compliance with the covenants of its credit facilities and letter of credit arrangements. BHE BHE has a $2.0 billion unsecured credit facility expiring in June 2019 with two one-year extension options subject to bank consent. The credit facility, which is for general corporate purposes and also supports BHE's commercial paper program and provides for the issuance of letters of credit, has a variable interest rate based on the LIBOR or a base rate, at BHE's option, plus a spread that varies based on BHE's senior unsecured long-term debt credit ratings. As of December 31, 2016 and 2015 , the weighted average interest rate on commercial paper borrowings outstanding was 0.88% and 0.66% , respectively. The credit facility requires that BHE's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.70 to 1.0 as of the last day of each quarter. As of December 31, 2016 and 2015 , BHE had $123 million and $142 million , respectively, of letters of credit outstanding, of which $7 million and $51 million as of December 31, 2016 and 2015 were issued under the credit facilities. These letters of credit primarily support power purchase agreements and debt service requirements at certain subsidiaries of BHE Renewables, LLC and expire through December 2018. PacifiCorp PacifiCorp has a $600 million unsecured credit facility expiring in March 2018 and a $400 million unsecured credit facility expiring in June 2019 each with two one-year extension options subject to bank consent. These credit facilities, which support PacifiCorp's commercial paper program, certain series of its tax-exempt bond obligations and provide for the issuance of letters of credit, have a variable interest rate based on LIBOR or a base rate, at PacifiCorp's option, plus a spread that varies based on PacifiCorp's credit ratings for its senior unsecured long-term debt securities. As of December 31, 2016 and 2015 , the weighted average interest rate on commercial paper borrowings outstanding was 0.96% and 0.65% , respectively. These credit facilities require that PacifiCorp's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.65 to 1.0 as of the last day of each quarter. As of December 31, 2016 and 2015 , PacifiCorp had $255 million and $310 million , respectively, of fully available letters of credit issued under committed arrangements, of which $10 million as of December 31, 2015 were issued under the credit facilities. These letters of credit support PacifiCorp's variable-rate tax-exempt bond obligations and expire through March 2019. MidAmerican Funding MidAmerican Energy has a $600 million unsecured credit facility expiring in March 2018 with two one-year extension options subject to bank consent. The credit facility, which supports MidAmerican Energy's commercial paper program and its variable-rate tax-exempt bond obligations and provides for the issuance of letters of credit, has a variable interest rate based on LIBOR or a base rate, at MidAmerican Energy's option, plus a spread that varies based on MidAmerican Energy's credit ratings for senior unsecured long-term debt securities. As of December 31, 2016 , the weighted average interest rate on commercial paper borrowings outstanding was 0.73% . The credit facility requires that MidAmerican Energy's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.65 to 1.0 as of the last day of each quarter. NV Energy Nevada Power has a $400 million secured credit facility expiring in March 2018 and Sierra Pacific has a $250 million secured credit facility expiring in March 2018 each with two one-year extension options subject to bank consent. These credit facilities, which are for general corporate purposes and provide for the issuance of letters of credit, have a variable interest rate based on LIBOR or a base rate, at each of the Nevada Utilities' option, plus a spread that varies based on each of the Nevada Utilities' credit ratings for its senior secured long-term debt securities. Amounts due under each credit facility are collateralized by each of the Nevada Utilities' general and refunding mortgage bonds. The credit facilities require that each of the Nevada Utilities' ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.68 to 1.0 as of the last day of each quarter. Northern Powergrid Northern Powergrid has a £150 million unsecured credit facility expiring in April 2020. The credit facility has a variable interest rate based on sterling LIBOR plus a spread that varies based on its credit ratings. The credit facility requires that the ratio of consolidated senior total net debt, including current maturities, to regulated asset value not exceed 0.8 to 1.0 at Northern Powergrid and 0.65 to 1.0 at Northern Powergrid (Northeast) Limited and Northern Powergrid (Yorkshire) plc as of June 30 and December 31. Northern Powergrid 's interest coverage ratio shall not be less than 2.5 to 1.0. AltaLink ALP has a C$750 million secured revolving credit facility expiring in December 2018 with a one-year extension option subject to bank consent. The credit facility, which provides support for borrowings under the unsecured commercial paper program and may also be used for general corporate purposes, has a variable interest rate based on the Canadian bank prime lending rate or a spread above the Bankers' Acceptance rate, at ALP 's option, based on ALP 's credit ratings for its senior secured long-term debt securities. In addition, ALP has a C$75 million secured revolving credit facility expiring in December 2018 with a one-year extension option subject to bank consent. The credit facility, which may be used for general corporate purposes, capital expenditures and letters of credit, has a variable interest rate based on the Canadian bank prime lending rate, United States base rate, United States LIBOR loan rate, or a spread above the Bankers' Acceptance rate, at ALP 's option, based on ALP 's credit ratings for its senior secured long-term debt securities. At the renewal date, ALP has the option to convert these facilities to one-year term facilities. The credit facilities require the consolidated indebtedness to total capitalization not exceed 0.75 to 1.0 measured as of the last day of each quarter. As of December 31, 2016 and 2015 , ALP had $26 million and $324 million outstanding under these facilities at a weighted average interest rate of 0.99% and 0.94% , respectively. AltaLink Investments, L.P. has a C$300 million unsecured revolving term credit facility expiring in December 2021 and a C$200 million unsecured revolving credit facility expiring in December 2017 each with a one-year extension option subject to bank consent. The credit facilities, which may be used for operating expenses, capital expenditures, working capital needs and letters of credit to a maximum of C$10 million , have a variable interest rate based on the Canadian bank prime lending rate, United States base rate, United States LIBOR loan rate, or a spread above the Bankers' Acceptance rate, at AltaLink Investments, L.P.'s option, based on AltaLink Investments, L.P.'s credit ratings for its senior unsecured long-term debt securities. The credit facilities require the consolidated total debt to capitalization to not exceed 0.8 to 1.0 and earnings before interest, taxes, depreciation and amortization to interest expense for the four fiscal quarters ended to not be less than 2.25 to 1.0 measured as of the last day of each quarter. As of December 31, 2016 and 2015 , AltaLink Investments, L.P. had $263 million and $77 million outstanding under these facilities at a weighted average interest rate of 1.74% and 2.09% , respectively. HomeServices HomeServices has a $350 million unsecured credit facility expiring in July 2018. The credit facility has a variable interest rate based on the prime lending rate or the LIBOR, at HomeServices' option, plus a spread that varies based on HomeServices' Total Leverage Ratio as defined in the agreement. As of December 31, 2016 , HomeServices had $50 million outstanding under its credit facility with a weighted average interest rate of 1.77% . Through its subsidiaries, HomeServices maintains mortgage lines of credit totaling $565 million and $578 million as of December 31, 2016 and 2015 , respectively, used for mortgage banking activities that expire beginning in February 2017 through December 2017 or are due on demand. The mortgage lines of credit have variable rates based on LIBOR plus a spread. Collateral for these credit facilities is comprised of residential property being financed and is equal to the loans funded with the facilities. As of December 31, 2016 and 2015 , HomeServices had $327 million and $300 million , respectively, outstanding under these mortgage lines of credit at a weighted average interest rate of 2.77% and 2.42% , respectively. BHE Renewables Letters of Credit In connection with their bond offerings, Topaz and Solar Star entered into separate letter of credit and reimbursement facilities totaling $627 million . Letters of credit issued under the letter of credit facilities will be used to (a) provide security under the power purchase agreement and large generator interconnection agreements, (b) fund the debt service reserve requirement and the operation and maintenance debt service reserve requirement and (c) provide security for remediation and mitigation liabilities. As of December 31, 2016 and 2015 , $599 million and $600 million , respectively, of letters of credit had been issued under these facilities. As of December 31, 2016 and 2015 , certain renewable projects collectively have letters of credit outstanding of $106 million and $65 million , respectively, primarily in support of the power purchase agreements associated with the projects.
PacifiCorp [Member]
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Short-term Debt and Other Financing Agreements The following table summarizes PacifiCorp's availability under its credit facilities as of December 31 (in millions): 2016: Credit facilities $ 1,000 Less: Short-term debt (270 ) Tax-exempt bond support (142 ) Net credit facilities $ 588 2015: Credit facilities $ 1,200 Less: Short-term debt (20 ) Tax-exempt bond support and letters of credit (160 ) Net credit facilities $ 1,020 PacifiCorp has a $600 million unsecured credit facility expiring in March 2018 and a $400 million unsecured credit facility with a stated maturity of June 2019 and which has two one-year extension options subject to bank consent. These credit facilities, which support PacifiCorp's commercial paper program, certain series of its tax-exempt bond obligations and provide for the issuance of letters of credit, have a variable interest rate based on the London Interbank Offered Rate or a base rate, at PacifiCorp's option, plus a spread that varies based on PacifiCorp's credit ratings for its senior unsecured long-term debt securities. As of December 31, 2016 and 2015 , the weighted average interest rate on commercial paper borrowings outstanding was 0.96% and 0.65% , respectively. These credit facilities require that PacifiCorp's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.65 to 1.0 as of the last day of each quarter. As of December 31, 2016 , PacifiCorp was in compliance with the covenants of its credit facilities. As of December 31, 2016 and 2015 , PacifiCorp had $255 million and $310 million , respectively, of fully available letters of credit issued under committed arrangements, of which $10 million as of December 31, 2015 were issued under the credit facilities. These letters of credit support PacifiCorp's variable-rate tax-exempt bond obligations and expire through March 2019. As of December 31, 2016 , PacifiCorp had approximately $14 million of additional letters of credit issued on its behalf to provide credit support for certain transactions as required by third parties. These letters of credit were all undrawn as of December 31, 2016 and have provisions that automatically extend the annual expiration dates for an additional year unless the issuing bank elects not to renew a letter of credit prior to the expiration date.
MidAmerican Energy Company [Member]
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Short-Term Debt and Credit Facilities Interim financing of working capital needs and the construction program is obtained from unaffiliated parties through the sale of commercial paper or short-term borrowing from banks. MidAmerican Energy has a $600 million unsecured credit facility expiring in March 2018 . The credit facility, which supports MidAmerican Energy's commercial paper program and its variable-rate tax-exempt bond obligations and provides for the issuance of letters of credit, has a variable interest rate based on the London Interbank Offered Rate ("LIBOR") or a base rate, at MidAmerican Energy's option, plus a spread that varies based on MidAmerican Energy's credit ratings for senior unsecured long-term debt securities. In addition, MidAmerican Energy has a $5 million unsecured credit facility, which expires in June 2017 and has a variable interest rate based on LIBOR plus a spread. As of December 31, 2016 , the weighted average interest rate on commercial paper borrowings outstanding was 0.73% . The $600 million credit facility requires that MidAmerican Energy's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.65 to 1.0 as of the last day of any quarter. As of December 31, 2016 , MidAmerican Energy was in compliance with the covenants of its credit facilities. MidAmerican Energy has authority from the FERC to issue commercial paper and bank notes aggregating $605 million through February 28, 2017 , and $905 million from March 1, 2017 , through February 28, 2019 . The following table summarizes MidAmerican Energy's availability under its two unsecured revolving credit facilities as of December 31 (in millions): 2016 2015 Credit facilities $ 605 $ 605 Less: Short-term debt outstanding (99 ) — Variable-rate tax-exempt bond support (220 ) (195 ) Net credit facilities $ 286 $ 410
MidAmerican Funding, LLC and Subsidiaries [Domain]
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Short-Term Debt and Credit Facilities Refer to Note 8 of MidAmerican Energy's Notes to Financial Statements. In addition to MidAmerican Energy's credit facilities, MHC has a $4 million unsecured credit facility, which expires in June 2017 and has a variable interest rate based on LIBOR plus a spread. As of December 31, 2016 and 2015 , there were no borrowings outstanding under this credit facility. As of December 31, 2016 , MHC was in compliance with the covenants of its credit facility.
Nevada Power Company [Member]
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Credit Facility Nevada Power has a $400 million secured credit facility expiring in March 2018. The credit facility, which is for general corporate purposes for the issuance of letters of credit, has a variable interest rate based on London Interbank Offered Rate or a base rate, at Nevada Power 's option, plus a spread that varies based on Nevada Power 's credit ratings for its senior secured long‑term debt securities. As of December 31 , 2016 and 2015 , Nevada Power had no borrowings outstanding under the credit facility. Amounts due under Nevada Power 's credit facility are collateralized by Nevada Power 's general and refunding mortgage bonds. The credit facility requires Nevada Power 's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.68 to 1.0 as of the last day of each quarter.
Sierra Pacific Power Company [Member]
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Credit Facility The following table summarizes Sierra Pacific's availability under its credit facilities as of December 31 (in millions): 2016 2015 Credit facilities $ 250 $ 250 Less - Water Facilities Refunding Revenue Bond support (80 ) — Net credit facilities $ 170 $ 250 Sierra Pacific has a $250 million secured credit facility expiring in March 2018. The credit facility, which is for general corporate purposes for the issuance of letters of credit, has a variable interest rate based on London Interbank Offered Rate or a base rate, at Sierra Pacific 's option, plus a spread that varies based on Sierra Pacific 's credit ratings for its senior secured long‑term debt securities. Amounts due under Sierra Pacific 's credit facility are collateralized by Sierra Pacific 's general and refunding mortgage bonds. The credit facility requires Sierra Pacific 's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.68 to 1.0 as of the last day of each quarter.

BHE Debt (Notes)

BHE Debt (Notes)	12 Months Ended
	Dec. 31, 2016
MEHC Debt [Abstract]
BHE Debt [Text Block]	BHE Debt Senior Debt BHE senior debt represents unsecured senior obligations of BHE that are redeemable in whole or in part at any time generally with make-whole premiums. BHE senior debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (in millions): Par Value 2016 2015 1.10% Senior Notes, due 2017 $ 400 $ 400 $ 399 5.75% Senior Notes, due 2018 650 649 648 2.00% Senior Notes, due 2018 350 349 348 2.40% Senior Notes, due 2020 350 349 348 3.75% Senior Notes, due 2023 500 497 497 3.50% Senior Notes, due 2025 400 397 397 8.48% Senior Notes, due 2028 475 477 477 6.125% Senior Bonds, due 2036 1,700 1,690 1,690 5.95% Senior Bonds, due 2037 550 547 547 6.50% Senior Bonds, due 2037 1,000 987 987 5.15% Senior Notes, due 2043 750 739 739 4.50% Senior Notes, due 2045 750 737 737 Total BHE Senior Debt $ 7,875 $ 7,818 $ 7,814 Reflected as: Current liabilities $ 400 $ — Noncurrent liabilities 7,418 7,814 Total BHE Senior Debt $ 7,818 $ 7,814 Junior Subordinated Debentures BHE junior subordinated debentures consists of the following as of December 31 (in millions): Par Value 2016 2015 Junior subordinated debentures, due 2043 $ — $ — $ 1,444 Junior subordinated debentures, due 2044 944 944 1,500 Total BHE junior subordinated debentures - noncurrent $ 944 $ 944 $ 2,944 BHE issued junior subordinated debentures to certain subsidiaries of Berkshire Hathaway pursuant to an indenture, by and between BHE and The Bank of New York Mellon Trust Company, N.A., as trustee, dated as of December 19, 2013 and November 12, 2014. The junior subordinated debentures are unsecured and junior in right of payment to BHE 's senior debt. The junior subordinated debentures (i) have a 30 year maturity; (ii) bear interest at a floating rate equal to (a) the greater of 1% and the LIBOR (the greater of such two rates, the "Base Rate") plus 200 basis points through the date prior to the third anniversary of the issuance date; (b) the Base Rate plus 300 basis points (or, if at least 50% of principal is repaid prior to the third anniversary of the issuance date, the Base Rate plus 200 basis points) from the third anniversary of the issuance date through the date prior to the seventh anniversary of the issuance date; and (c) the Base Rate plus 375 basis points from the seventh anniversary of the issuance date until the maturity of the junior subordinated debentures; and (iii) are redeemable at BHE 's option from time to time at par plus accrued and unpaid interest. The holders are restricted from transferring the junior subordinated debentures except to Berkshire Hathaway and its subsidiaries. As of December 31, 2016 and 2015 , the interest rate was 3.0% . Interest expense to Berkshire Hathaway for the years ended December 31, 2016 , 2015 and 2014 was $65 million , $104 million and $78 million , respectively. In February 2017, BHE provided notice of redemption for $ 200 million of the junior subordinated debentures due 2044 at par value to occur in March 2017.

Subsidiary Debt (Notes)

Subsidiary Debt (Notes)	12 Months Ended
	Dec. 31, 2016
Debt Instrument [Line Items]
Subsidiary Debt	Subsidiary Debt BHE 's direct and indirect subsidiaries are organized as legal entities separate and apart from BHE and its other subsidiaries. Pursuant to separate financing agreements, substantially all of PacifiCorp's electric utility properties; the equity interest of MidAmerican Funding's subsidiary; MidAmerican Energy's electric utility properties in the state of Iowa; substantially all of Nevada Power's and Sierra Pacific's properties in the state of Nevada; the long-term customer contracts of Kern River; AltaLink's transmission properties; and substantially all of the assets of the subsidiaries of BHE Renewables are pledged or encumbered to support or otherwise provide the security for their related subsidiary debt. It should not be assumed that the assets of any subsidiary will be available to satisfy BHE 's obligations or the obligations of its other subsidiaries. However, unrestricted cash or other assets which are available for distribution may, subject to applicable law, regulatory commitments and the terms of financing and ring-fencing arrangements for such parties, be advanced, loaned, paid as dividends or otherwise distributed or contributed to BHE or affiliates thereof. The long-term debt of subsidiaries may include provisions that allow BHE 's subsidiaries to redeem it in whole or in part at any time. These provisions generally include make-whole premiums. Distributions at these separate legal entities are limited by various covenants including, among others, leverage ratios, interest coverage ratios and debt service coverage ratios. As of December 31, 2016 , all subsidiaries were in compliance with their long-term debt covenants. Long-term debt of subsidiaries consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31 (in millions): Par Value 2016 2015 PacifiCorp $ 7,120 $ 7,079 $ 7,159 MidAmerican Funding 4,657 4,592 4,560 NV Energy 4,569 4,582 4,860 Northern Powergrid 2,351 2,379 2,772 BHE Pipeline Group 995 990 1,040 BHE Transmission 4,068 4,058 3,467 BHE Renewables 3,716 3,674 3,356 Total subsidiary debt $ 27,476 $ 27,354 $ 27,214 Reflected as: Current liabilities $ 606 $ 1,148 Noncurrent liabilities 26,748 26,066 Total subsidiary debt $ 27,354 $ 27,214 PacifiCorp PacifiCorp's long-term debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 First mortgage bonds: 3.85% to 8.53%, due through 2021 $ 1,272 $ 1,269 $ 1,271 2.95% to 8.27%, due 2022 to 2026 1,829 1,820 1,819 7.70% due 2031 300 298 298 5.25% to 6.10%, due 2034 to 2036 850 843 843 5.75% to 6.35%, due 2037 to 2039 2,150 2,134 2,133 4.10% due 2042 300 297 297 Variable-rate series, tax-exempt bond obligations (2016-0.69% to 0.86%; 2015-0.01% to 0.22%): Due 2017 to 2018 91 91 91 Due 2018 to 2025 (1) 108 108 107 Due 2024 (1)(2) 143 142 196 Due 2024 to 2025 (2) 50 50 59 Capital lease obligations - 8.75% to 14.61%, due through 2035 27 27 45 Total PacifiCorp $ 7,120 $ 7,079 $ 7,159 (1) Supported by $255 million and $310 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2016 and 2015 , respectively. (2) Secured by pledged first mortgage bonds registered to and held by the tax-exempt bond trustee generally with the same interest rates, maturity dates and redemption provisions as the tax-exempt bond obligations. The issuance of PacifiCorp's first mortgage bonds is limited by available property, earnings tests and other provisions of PacifiCorp's mortgage. Approximately $26 billion of PacifiCorp's eligible property (based on original cost) was subject to the lien of the mortgage as of December 31, 2016 . MidAmerican Funding MidAmerican Funding's long-term debt consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 MidAmerican Funding: 6.927% Senior Bonds, due 2029 $ 325 $ 291 $ 289 MidAmerican Energy: Tax-exempt bond obligations - Variable-rate tax-exempt bond obligation series: (2016-0.76%, 2015-0.03%), due 2023-2046 220 219 194 First Mortgage Bonds: 2.40%, due 2019 500 499 499 3.70%, due 2023 250 248 248 3.50%, due 2024 500 501 502 4.80%, due 2043 350 345 345 4.40%, due 2044 400 394 394 4.25%, due 2046 450 445 444 Notes: 5.95% Series, due 2017 250 250 250 5.3% Series, due 2018 350 350 349 6.75% Series, due 2031 400 396 395 5.75% Series, due 2035 300 298 298 5.8% Series, due 2036 350 347 347 Transmission upgrade obligation, 4.45% and 3.42% due through 2035 and 2036, respectively 10 7 4 Capital lease obligations - 4.16%, due through 2020 2 2 2 Total MidAmerican Energy 4,332 4,301 4,271 Total MidAmerican Funding $ 4,657 $ 4,592 $ 4,560 In February 2017, MidAmerican Energy issued $375 million of its 3.10% First Mortgage Bonds due May 2027 and $475 million of its 3.95% First Mortgage Bonds due August 2047. An amount equal to the net proceeds will be used to finance capital expenditures, disbursed during the period from February 2, 2016 to February 1, 2017, with respect to investments in MidAmerican Energy's 551-megawatt Wind X and 2,000-megawatt Wind XI projects, which were previously financed with MidAmerican Energy's general funds. In January 2017, MidAmerican Energy provided notice to holders of its $250 million of 5.95% Senior Notes due July 2017 that MidAmerican Energy would redeem such notes in full through optional redemption on February 27, 2017. Pursuant to MidAmerican Energy's mortgage dated September 9, 2013, MidAmerican Energy's first mortgage bonds, currently and from time to time outstanding, are secured by a first mortgage lien on substantially all of its electric generating, transmission and distribution property within the state of Iowa, subject to certain exceptions and permitted encumbrances. As of December 31, 2016 , MidAmerican Energy's eligible property subject to the lien of the mortgage totaled approximately $15 billion based on original cost. Additionally, MidAmerican Energy's senior notes outstanding are equally and ratably secured with the first mortgage bonds as required by the indentures under which the senior notes were issued. NV Energy NV Energy's long-term debt consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 NV Energy - 6.250% Senior Notes, due 2020 $ 315 $ 363 $ 373 Nevada Power: General and refunding mortgage securities: 5.950% Series M, due 2016 — — 210 6.500% Series O, due 2018 324 324 323 6.500% Series S, due 2018 499 498 498 7.125% Series V, due 2019 500 499 499 6.650% Series N, due 2036 367 357 356 6.750% Series R, due 2037 349 345 345 5.375% Series X, due 2040 250 247 247 5.450% Series Y, due 2041 250 236 235 Variable-rate series (2016-1.890% to 1.928%, 2015-0.672% to 1.055%): Pollution Control Revenue Bonds Series 2006A, due 2032 38 38 38 Pollution Control Revenue Bonds Series 2006, due 2036 38 37 37 Capital and financial lease obligations - 2.750% to 11.600%, due through 2054 485 485 497 Total Nevada Power 3,100 3,066 3,285 Sierra Pacific: General and refunding mortgage securities: 6.000% Series M, due 2016 — — 450 3.375% Series T, due 2023 250 248 248 2.600% Series U, due 2026 400 395 — 6.750% Series P, due 2037 252 255 255 Tax-exempt refunding revenue bond obligations: Fixed-rate series: 1.250% Pollution Control Series 2016A, due 2029 20 20 — 1.500% Gas Facilities Series 2016A, due 2031 58 58 — 3.000% Gas and Water Series 2016B, due 2036 60 64 — Variable-rate series (2016-0.788% to 0.800%, 2015-0.733% to 1.054%): Pollution Control Series 2006A, due 2031 — — 58 Pollution Control Series 2006B, due 2036 — — 74 Pollution Control Series 2006C, due 2036 — — 80 Water Facilities Series 2016C, due 2036 30 29 — Water Facilities Series 2016D, due 2036 25 25 — Water Facilities Series 2016E, due 2036 25 25 — Capital and financial lease obligations - 2.700% to 10.130%, due through 2054 34 34 37 Total Sierra Pacific 1,154 1,153 1,202 Total NV Energy $ 4,569 $ 4,582 $ 4,860 The issuance of General and Refunding Mortgage Securities by the Nevada Utilities is subject to PUCN approval and is limited by available property and other provisions of the mortgage indentures for each of Nevada Power and Sierra Pacific. As of December 31, 2016 , approximately $8.9 billion of Nevada Power's and $3.8 billion of Sierra Pacific's (based on original cost) property was subject to the liens of the mortgages. Northern Powergrid Northern Powergrid and its subsidiaries' long-term debt consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value (1) 2016 2015 8.875% Bonds, due 2020 $ 123 $ 136 $ 162 9.25% Bonds, due 2020 247 259 315 3.901% to 4.586% European Investment Bank loans, due 2018 to 2022 333 333 398 7.25% Bonds, due 2022 247 257 306 2.50% Bonds due 2025 185 182 217 2.073% European Investment Bank loan, due 2025 62 62 — 2.564% European Investment Bank loans, due 2027 308 308 368 7.25% Bonds, due 2028 229 234 280 4.375% Bonds, due 2032 185 182 217 5.125% Bonds, due 2035 247 243 291 5.125% Bonds, due 2035 185 183 218 Total Northern Powergrid $ 2,351 $ 2,379 $ 2,772 (1) The par values for these debt instruments are denominated in sterling. BHE Pipeline Group BHE Pipeline Group ' long-term debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 Northern Natural Gas: 5.75% Senior Notes, due 2018 $ 200 $ 199 $ 199 4.25% Senior Notes, due 2021 200 199 199 5.8% Senior Bonds, due 2037 150 149 149 4.1% Senior Bonds, due 2042 250 248 248 Total Northern Natural Gas 800 795 795 Kern River: 4.893% Senior Notes, due 2018 195 195 245 Total BHE Pipeline Group $ 995 $ 990 $ 1,040 Kern River's long-term debt amortizes monthly. Kern River redeemed the remaining amount of its 6.676% Senior Notes due 2016 at a redemption price determined in accordance with the terms of the indenture. Kern River provides a debt service reserve letter of credit to cover the next six months of principal and interest payments due on the loans, which were equal to $35 million and $33 million as of December 31, 2016 and 2015 , respectively. BHE Transmission BHE Transmission 's long-term debt consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31, (dollars in millions): Par Value (1) 2016 2015 AltaLink Investments, L.P.: Series 09-1 Senior Bonds, 5.207%, due 2016 $ — $ — $ 112 Series 12-1 Senior Bonds, 3.674%, due 2019 149 153 151 Series 13-1 Senior Bonds, 3.265%, due 2020 149 152 149 Series 15-1 Senior Bonds, 2.244%, due 2022 149 148 144 Total AltaLink Investments, L.P. 447 453 556 AltaLink, L.P.: Series 2008-1 Notes, 5.243%, due 2018 149 148 145 Series 2013-2 Notes, 3.621%, due 2020 93 93 90 Series 2012-2 Notes, 2.978%, due 2022 204 204 198 Series 2013-4 Notes, 3.668%, due 2023 372 371 360 Series 2014-1 Notes, 3.399%, due 2024 260 260 252 Series 2016-1 Notes, 2.747%, due 2026 260 259 — Series 2006-1 Notes, 5.249%, due 2036 112 111 108 Series 2010-1 Notes, 5.381%, due 2040 93 93 90 Series 2010-2 Notes, 4.872%, due 2040 112 111 108 Series 2011-1 Notes, 4.462%, due 2041 205 204 198 Series 2012-1 Notes, 3.99%, due 2042 391 385 374 Series 2013-3 Notes, 4.922%, due 2043 260 260 252 Series 2014-3 Notes, 4.054%, due 2044 219 218 212 Series 2015-1 Notes, 4.090%, due 2045 260 259 251 Series 2016-2 Notes, 3.717%, due 2046 335 333 — Series 2013-1 Notes, 4.446%, due 2053 186 186 180 Series 2014-2 Notes, 4.274%, due 2064 97 97 93 Total AltaLink, L.P. 3,608 3,592 2,911 Other: Construction Loan, 4.950%, due 2021 13 13 — Total BHE Transmission $ 4,068 $ 4,058 $ 3,467 (1) The par values for these debt instruments are denominated in Canadian dollars. BHE Renewables BHE Renewables ' long-term debt consists of the following, including fair value adjustments and unamortized debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 Fixed-rate (1) : CE Generation Bonds, 7.416%, due 2018 $ 67 $ 67 $ 97 Salton Sea Funding Corporation Bonds, 7.475%, due 2018 30 31 51 Cordova Funding Corporation Bonds, 8.48% to 9.07%, due 2019 96 97 113 Bishop Hill Holdings Senior Notes, 5.125%, due 2032 100 99 102 Solar Star Funding Senior Notes, 3.950%, due 2035 316 311 321 Solar Star Funding Senior Notes, 5.375%, due 2035 977 966 988 Grande Prairie Wind Senior Notes, 3.860%, due 2037 419 414 — Topaz Solar Farms Senior Notes, 5.750%, due 2039 791 780 815 Topaz Solar Farms Senior Notes, 4.875%, due 2039 230 229 239 Other 22 22 25 Variable-rate (1) : Pinyon Pines I and II Term Loans, due 2019 (2) 356 355 378 Wailuku Special Purpose Revenue Bonds, 0.90%, due 2021 7 7 8 TX Jumbo Road Term Loan, due 2025 (2) 212 206 219 Marshall Wind Term Loan, due 2026 (2) 93 90 — Total BHE Renewables $ 3,716 $ 3,674 $ 3,356 (1) Amortizes quarterly or semiannually. (2) The term loans have variable interest rates based on LIBOR plus a margin that varies during the terms of the agreements. The Company has entered into interest rate swaps that fix the interest rate on 75% of the Pinyon Pines outstanding debt and 100% of the TX Jumbo Road and Marshall Wind outstanding debt. The variable interest rate as of December 31, 2016 and 2015 was 2.62% and 2.23% , respectively, while the fixed interest rates ranged from 3.21% to 3.63% as of December 31, 2016 , and 3.55% to 3.63% as of December 31, 2015 . Annual Repayments of Long-Term Debt The annual repayments of BHE and subsidiary debt for the years beginning January 1, 2017 and thereafter, excluding fair value adjustments and unamortized premiums, discounts and debt issuance costs, are as follows (in millions): 2022 and 2017 2018 2019 2020 2021 Thereafter Total BHE senior notes $ 400 $ 1,000 $ — $ 350 $ — $ 6,125 $ 7,875 BHE junior subordinated debentures — — — — — 944 944 PacifiCorp 58 588 352 40 425 5,657 7,120 MidAmerican Funding 251 351 500 2 1 3,552 4,657 NV Energy 18 840 519 336 27 2,829 4,569 Northern Powergrid — 49 49 418 — 1,835 2,351 BHE Pipeline Group 66 329 — — 200 400 995 BHE Transmission — 151 151 245 3 3,518 4,068 BHE Renewables 213 236 528 161 167 2,411 3,716 Totals $ 1,006 $ 3,544 $ 2,099 $ 1,552 $ 823 $ 27,271 $ 36,295
PacifiCorp [Member]
Debt Instrument [Line Items]
Debt and Capital Leases Disclosures [Text Block]	Long-term Debt and Capital Lease Obligations PacifiCorp's long-term debt and capital lease obligations were as follows as of December 31 (dollars in millions): 2016 2015 Average Average Principal Carrying Interest Carrying Interest Amount Value Rate Value Rate First mortgage bonds: 3.85% to 8.53%, due through 2021 $ 1,272 $ 1,269 5.10 % $ 1,271 5.10 % 2.95% to 8.27%, due 2022 to 2026 1,829 1,820 4.10 1,819 4.10 7.70% due 2031 300 298 7.70 298 7.70 5.25% to 6.10%, due 2034 to 2036 850 843 5.80 843 5.80 5.75% to 6.35%, due 2037 to 2039 2,150 2,134 6.00 2,133 6.00 4.10% due 2042 300 297 4.10 297 4.10 Variable-rate series, tax-exempt bond obligations (2016-0.69% to 0.86%; 2015-0.01% to 0.22%): Due 2017 to 2018 91 91 0.85 91 0.22 Due 2018 to 2025 (1) 108 108 0.74 107 0.01 Due 2024 (1)(2) 143 142 0.70 196 0.02 Due 2024 to 2025 (2) 50 50 0.80 59 0.21 Total long-term debt 7,093 7,052 7,114 Capital lease obligations: 8.75% to 14.61%, due through 2035 27 27 11.09 32 11.25 Total long-term debt and capital lease obligations $ 7,120 $ 7,079 $ 7,146 Reflected as: 2016 2015 Current portion of long-term debt and capital lease obligations $ 58 $ 68 Long-term debt and capital lease obligations 7,021 7,078 Total long-term debt and capital lease obligations $ 7,079 $ 7,146 1) Supported by $255 million and $310 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2016 and 2015 , respectively. 2) Secured by pledged first mortgage bonds registered to and held by the tax-exempt bond trustee generally with the same interest rates, maturity dates and redemption provisions as the tax-exempt bond obligations. PacifiCorp's long-term debt generally includes provisions that allow PacifiCorp to redeem the first mortgage bonds in whole or in part at any time through the payment of a make-whole premium. Variable-rate tax-exempt bond obligations are generally redeemable at par value. PacifiCorp currently has regulatory authority from the OPUC and the IPUC to issue an additional $1.325 billion of long-term debt. PacifiCorp must make a notice filing with the Washington Utilities and Transportation Commission prior to any future issuance. PacifiCorp currently has an effective shelf registration statement filed with the United States Securities and Exchange Commission to issue up to $1.325 billion additional first mortgage bonds through January 2019. The issuance of PacifiCorp's first mortgage bonds is limited by available property, earnings tests and other provisions of PacifiCorp's mortgage. Approximately $26 billion of PacifiCorp's eligible property (based on original cost) was subject to the lien of the mortgage as of December 31, 2016 . PacifiCorp has entered into long-term agreements that qualify as capital leases and expire at various dates through March 2035 for transportation services, a power purchase agreement and real estate. The transportation services agreements included as capital leases are for the right to use pipeline facilities to provide natural gas to two of PacifiCorp's generating facilities. Net capital lease assets of $27 million and $32 million as of December 31, 2016 and 2015 , respectively, were included in property, plant and equipment, net in the Consolidated Balance Sheets. As of December 31, 2016 , the annual principal maturities of long-term debt and total capital lease obligations for 2017 and thereafter are as follows (in millions): Long-term Capital Lease Debt Obligations Total 2017 $ 52 $ 9 $ 61 2018 586 4 590 2019 350 4 354 2020 38 3 41 2021 420 6 426 Thereafter 5,647 20 5,667 Total 7,093 46 7,139 Unamortized discount and debt issuance costs (41 ) — (41 ) Amounts representing interest — (19 ) (19 ) Total $ 7,052 $ 27 $ 7,079
MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Long-term Debt [Text Block]	Long-Term Debt MidAmerican Energy's long-term debt consists of the following, including amounts maturing within one year and unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 First mortgage bonds: 2.40%, due 2019 $ 500 $ 499 $ 499 3.70%, due 2023 250 248 248 3.50%, due 2024 500 501 502 4.80%, due 2043 350 345 345 4.40%, due 2044 400 394 394 4.25%, due 2046 450 445 444 Notes: 5.95% Series, due 2017 250 250 250 5.3% Series, due 2018 350 350 349 6.75% Series, due 2031 400 396 395 5.75% Series, due 2035 300 298 298 5.8% Series, due 2036 350 347 347 Transmission upgrade obligation, 4.45% and 3.42% due through 2035 and 2036, respectively 10 7 4 Variable-rate tax-exempt bond obligation series: (weighted average interest rate- 2016-0.76%, 2015-0.03%): Due 2016 — — 33 Due 2017 — — 4 Due 2023, issued in 1993 7 7 7 Due 2023, issued in 2008 57 57 57 Due 2024 35 35 35 Due 2025 13 13 13 Due 2036 33 33 — Due 2038 45 45 45 Due 2046 30 29 — Capital lease obligations - 4.16%, due through 2020 2 2 2 Total $ 4,332 $ 4,301 $ 4,271 The annual repayments of MidAmerican Energy's long-term debt for the years beginning January 1, 2017 , and thereafter, excluding unamortized premiums, discounts and debt issuance costs, are as follows (in millions): 2017 $ 251 2018 351 2019 500 2020 2 2021 1 2022 and thereafter 3,227 Pursuant to MidAmerican Energy's mortgage dated September 9, 2013, MidAmerican Energy's first mortgage bonds, currently and from time to time outstanding, are secured by a first mortgage lien on substantially all of its electric generating, transmission and distribution property within the State of Iowa, subject to certain exceptions and permitted encumbrances. As of December 31, 2016 , MidAmerican Energy's eligible property subject to the lien of the mortgage totaled approximately $15 billion based on original cost. Additionally, MidAmerican Energy's senior notes outstanding are equally and ratably secured with the first mortgage bonds as required by the indentures under which the senior notes were issued. MidAmerican Energy's variable-rate tax-exempt obligations, including the tax-exempt bonds discussed above, bear interest at rates that are periodically established through remarketing of the bonds in the short-term tax-exempt market. MidAmerican Energy, at its option, may change the mode of interest calculation for these bonds by selecting from among several floating or fixed rate alternatives. The interest rates shown in the table above are the weighted average interest rates as of December 31, 2016 and 2015 . MidAmerican Energy maintains revolving credit facility agreements to provide liquidity for holders of these issues. In September 2016, the Iowa Finance Authority issued $33 million of variable-rate tax-exempt Pollution Control Facilities Refunding Revenue Bonds due September 2036, the proceeds of which were loaned to MidAmerican Energy to refinance, in September 2016, variable-rate tax-exempt pollution control refunding revenue bonds totaling $29 million due September 2016 and $4 million due March 2017, which were optionally redeemed in full. In December 2016, the Iowa Finance Authority issued $30 million of its variable-rate, tax-exempt Solid Waste Facilities Revenue Bonds due December 2046, the proceeds of which were loaned to MidAmerican Energy for purpose of constructing solid waste facilities. The bonds are secured by an equal amount of first mortgage bonds pursuant to MidAmerican Energy's mortgage dated September 9, 2013, as supplemented and amended. As of December 31, 2016 , MidAmerican Energy was in compliance with all of its applicable long-term debt covenants. In March 1999, MidAmerican Energy committed to the IUB to use commercially reasonable efforts to maintain an investment grade rating on its long-term debt and to maintain its common equity level above 42% of total capitalization unless circumstances beyond its control result in the common equity level decreasing to below 39% of total capitalization. MidAmerican Energy must seek the approval from the IUB of a reasonable utility capital structure if MidAmerican Energy's common equity level decreases below 42% of total capitalization, unless the decrease is beyond the control of MidAmerican Energy. MidAmerican Energy is also required to seek the approval of the IUB if MidAmerican Energy's equity level decreases to below 39% , even if the decrease is due to circumstances beyond the control of MidAmerican Energy. As of December 31, 2016 , MidAmerican Energy's common equity ratio was 53% computed on a basis consistent with its commitment. As a result of its regulatory commitment to maintain its common equity level above certain thresholds, MidAmerican Energy could dividend $2.0 billion as of December 31, 2016 , without falling below 42% .
MidAmerican Funding, LLC and Subsidiaries [Domain]
Debt Instrument [Line Items]
Long-term Debt [Text Block]	Long-Term Debt Refer to Note 9 of MidAmerican Energy's Notes to Financial Statements for detail and a discussion of its long-term debt. In addition to MidAmerican Energy's annual repayments of long-term debt, MidAmerican Funding has $325 million of long-term debt due in 2029 , with a carrying value of $326 million as of December 31, 2016 and 2015 . MidAmerican Funding parent company long-term debt is secured by a pledge of the common stock of MHC. See Item 15(c) for the Consolidated Financial Statements of MHC Inc. and subsidiaries. The bonds are the direct senior secured obligations of MidAmerican Funding and effectively rank junior to all indebtedness and other liabilities of the direct and indirect subsidiaries of MidAmerican Funding, to the extent of the assets of these subsidiaries. MidAmerican Funding may redeem the bonds in whole or in part at any time at a redemption price equal to the sum of any accrued and unpaid interest to the date of redemption and the greater of (1) 100% of the principal amount of the bonds or (2) the sum of the present values of the remaining scheduled payments of principal and interest on the bonds, discounted to the date of redemption on a semiannual basis at the treasury yield plus 25 basis points. Subsidiaries of MidAmerican Funding must make payments on their own indebtedness before making distributions to MidAmerican Funding. Refer to Note 9 of MidAmerican Energy's Notes to Financial Statements for a discussion of utility regulatory restrictions affecting distributions from MidAmerican Energy. As a result of the utility regulatory restrictions agreed to by MidAmerican Energy in March 1999, MidAmerican Funding had restricted net assets of $3.1 billion as of December 31, 2016 . As of December 31, 2016 , MidAmerican Funding was in compliance with all of its applicable long-term debt covenants. Each of MidAmerican Funding's direct or indirect subsidiaries is organized as a legal entity separate and apart from MidAmerican Funding and its other subsidiaries. It should not be assumed that any asset of any subsidiary of MidAmerican Funding will be available to satisfy the obligations of MidAmerican Funding or any of its other subsidiaries; provided, however, that unrestricted cash or other assets which are available for distribution may, subject to applicable law and the terms of financing arrangements of such parties, be advanced, loaned, paid as dividends or otherwise distributed or contributed to MidAmerican Funding, one of its subsidiaries or affiliates thereof.
Nevada Power Company [Member]
Debt Instrument [Line Items]
Debt Disclosure [Text Block]	Long-Term Debt and Financial and Capital Lease Obligations Nevada Power 's long-term debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 General and refunding mortgage securities: 5.950% Series M, due 2016 — — 210 6.500% Series O, due 2018 324 324 323 6.500% Series S, due 2018 499 498 498 7.125% Series V, due 2019 500 499 499 6.650% Series N, due 2036 367 357 356 6.750% Series R, due 2037 349 345 345 5.375% Series X, due 2040 250 247 247 5.450% Series Y, due 2041 250 236 235 Variable-rate series (2016-1.890% to 1.928%, 2015-0.672% to 1.055%): Pollution Control Revenue Bonds Series 2006A, due 2032 38 38 38 Pollution Control Revenue Bonds Series 2006, due 2036 38 37 37 Capital and financial lease obligations - 2.750% to 11.600%, due through 2054 485 485 497 Total long-term debt and financial and capital leases $ 3,100 $ 3,066 $ 3,285 Reflected as: Current portion of long-term debt and financial and capital lease obligations $ 17 $ 225 Long-term debt and financial and capital lease obligations 3,049 3,060 Total long-term debt and financial and capital leases $ 3,066 $ 3,285 In January 2017, Nevada Power (1) issued a notice to the bondholders for the repurchase of the remaining outstanding amounts of its $38 million Pollution Control Revenue Bonds Series 2006 and $38 million Pollution Control Revenue Bonds Series 2006A and (2) redeemed the Pollution Control Revenue Bonds Series 2006A aggregate principal amount outstanding plus accrued interest with the use of cash on hand. In February 2017, Nevada Power redeemed the Pollution Control Revenue Bonds Series 2006 aggregate principal amount outstanding plus accrued interest with the use of cash on hand. Annual Payment on Long-Term Debt and Financial and Capital Leases The annual repayments of long-term debt and capital and financial leases for the years beginning January 1, 2017 and thereafter, are as follows (in millions): Long-term Capital and Financial Debt Lease Obligations Total 2017 $ — $ 75 $ 75 2018 823 74 897 2019 500 76 576 2020 — 75 75 2021 — 79 79 Thereafter 1,292 831 2,123 Total 2,615 1,210 3,825 Unamortized premium, discount and debt issuance cost (34 ) — (34 ) Executory costs — (111 ) (111 ) Amounts representing interest — (614 ) (614 ) Total $ 2,581 $ 485 $ 3,066 The issuance of General and Refunding Mortgage Securities by Nevada Power is subject to PUCN approval and is limited by available property and other provisions of the mortgage indentures. As of December 31, 2016 , approximately $8.9 billion (based on original cost) of Nevada Power ’s property was subject to the liens of the mortgages. Financial and Capital Lease Obligations • In 1984, Nevada Power entered into a 30 -year capital lease for the Pearson Building with five , five -year renewal options beginning in year 2015. In February 2010, Nevada Power amended this capital lease agreement to include the lease of the adjoining parking lot and to exercise three of the five -year renewal options beginning in year 2015. There remain two additional renewal options which could extend the lease an additional ten years. Capital assets of $25 million and $27 million were included in property, plant and equipment, net as of December 31 , 2016 and 2015 , respectively. • In 2007, Nevada Power entered into a 20 -year lease, with three 10 -year renewal options, to occupy land and building for its Beltway Complex operations center in southern Nevada. Nevada Power accounts for the building portion of the lease as a capital lease and the land portion of the lease as an operating lease. Nevada Power transferred operations to the facilities in June 2009. Capital assets of $7 million were included in property, plant and equipment, net as of December 31 , 2016 and 2015 . • Nevada Power has long-term energy purchase contracts which qualify as capital leases. The leases were entered into between the years 1989 and 1990 and became commercially operable through 1993. The terms of the leases are for 30 years and expire between the years 2022-2023. Capital assets of $38 million and $40 million were included in property, plant and equipment, net as of December 31 , 2016 and 2015 , respectively. • Nevada Power has master leasing agreements of which various pieces of equipment qualify as capital leases. The remaining equipment is treated as operating leases. Lease terms average seven years under the master lease agreement. Capital assets of $1 million were included in property, plant and equipment, net as of December 31 , 2016 and 2015 . • ON Line was placed in-service on December 31 , 2013. The Nevada Utilities entered into a long-term transmission use agreement, in which the Nevada Utilities have 25% interest and Great Basin Transmission South, LLC has 75% interest. Refer to Note 4 for additional information. The Nevada Utilities ' share of the long-term transmission use agreement and ownership interest is split at 95% for Nevada Power and 5% for Sierra Pacific. The term is for 41 years with the agreement ending December 31 , 2054. Payments began on January 31, 2014. ON Line assets of $402 million and $410 million were included in property, plant and equipment, net as of December 31 , 2016 and 2015 , respectively.
Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Debt Disclosure [Text Block]	Long-Term Debt and Financial and Capital Lease Obligations Sierra Pacific 's long-term debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 General and refunding mortgage securities: 6.000% Series M, due 2016 $ — $ — $ 450 3.375% Series T, due 2023 250 248 248 2.600% Series U, due 2026 400 395 — 6.750% Series P, due 2037 252 255 255 Tax-exempt refunding revenue bond obligations: Fixed-rate series: 1.250% Pollution Control Series 2016A, due 2029 (1) 20 20 — 1.500% Gas Facilities Series 2016A, due 2031 (1) 58 58 — 3.000% Gas and Water Series 2016B, due 2036 (2) 60 64 — Variable-rate series (2016-0.788% to 0.800%, 2015-0.733% to 1.054%): Pollution Control Series 2006A, due 2031 — — 58 Pollution Control Series 2006B, due 2036 — — 74 Pollution Control Series 2006C, due 2036 — — 80 Water Facilities Series 2016C, due 2036 30 29 — Water Facilities Series 2016D, due 2036 25 25 — Water Facilities Series 2016E, due 2036 25 25 — Capital and financial lease obligations - 2.700% to 10.130%, due through 2054 34 34 37 Total long-term debt and financial and capital leases $ 1,154 $ 1,153 $ 1,202 Reflected as: Current portion of long-term debt and financial and capital lease obligations $ 1 $ 453 Long-term debt and financial and capital lease obligations 1,152 749 Total long-term debt and financial and capital leases $ 1,153 $ 1,202 (1) Subject to mandatory purchase by Sierra Pacific in June 2019 at which date the interest rate may be adjusted from time to time. (2) Subject to mandatory purchase by Sierra Pacific in June 2022 at which date the interest rate may be adjusted from time to time. Annual Payment on Long-Term Debt and Financial and Capital Leases The annual repayments of long-term debt and capital and financial leases for the years beginning January 1, 2017 and thereafter, are as follows (in millions): Long-term Capital and Financial Debt Lease Obligations Total 2017 $ — $ 4 $ 4 2018 — 4 4 2019 — 4 4 2020 — 4 4 2021 — 3 3 Thereafter 1,120 50 1,170 Total 1,120 69 1,189 Unamortized premium, discount and debt issuance cost (1 ) — (1 ) Amounts representing interest — (35 ) (35 ) Total $ 1,119 $ 34 $ 1,153 The issuance of General and Refunding Mortgage Securities by Sierra Pacific is subject to PUCN approval and is limited by available property and other provisions of the mortgage indentures. As of December 31, 2016 , approximately $3.8 billion (based on original cost) of Sierra Pacific ’s property was subject to the liens of the mortgages. Financial and Capital Lease Obligations • Sierra Pacific has master leasing agreements of which various pieces of equipment qualify as capital leases. The remaining equipment is treated as operating leases. Lease terms average seven years under the master lease agreement. Capital assets of $3 million were included in property, plant and equipment, net as of December 31 , 2016 and 2015 . • ON Line was placed in-service on December 31, 2013. The Nevada Utilities entered into a long-term transmission use agreement, in which the Nevada Utilities have 25% interest and Great Basin Transmission South, LLC has 75% interest. Refer to Note 4 for additional information. The Nevada Utilities share of the long-term transmission use agreement and ownership interest is split at 5% for Sierra Pacific and 95% for Nevada Power. The term is for 41 years with the agreement ending December 31, 2054. Payments began on January 31, 2014. ON Line assets of $21 million and $22 million were included in property, plant and equipment, net as of December 31 , 2016 and 2015 , respectively. • In 2015, Sierra Pacific entered into a 20 -year capital lease for the Fort Churchill Solar Array. Capital assets of $10 million and $12 million were included in property, plant and equipment, net as of December 31 , 2016 and 2015 , respectively.

Risk Management and Hedging Act

Risk Management and Hedging Activities (Notes)	12 Months Ended
	Dec. 31, 2016
Derivative [Line Items]
Risk Management and Hedging Activities [Text Block]	Risk Management and Hedging Activities The Company is exposed to the impact of market fluctuations in commodity prices, interest rates and foreign currency exchange rates. The Company is principally exposed to electricity, natural gas, coal and fuel oil commodity price risk primarily through BHE's ownership of the Utilities as they have an obligation to serve retail customer load in their regulated service territories. The Company also provides nonregulated retail electricity and natural gas services in competitive markets. The Utilities' load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity, wholesale electricity that is purchased and sold, and natural gas supply for retail customers. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather, market liquidity, generating facility availability, customer usage, storage, and transmission and transportation constraints. Interest rate risk exists on variable-rate short- and long-term debt, future debt issuances and mortgage commitments. Additionally, the Company is exposed to foreign currency exchange rate risk from its business operations and investments in Great Britain and Canada. The Company does not engage in a material amount of proprietary trading activities. Each of the Company's business platforms has established a risk management process that is designed to identify, assess, manage, mitigate, monitor and report each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, the Company uses commodity derivative contracts, which may include forwards, futures, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. The Company manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed-rate long-term debt and by monitoring market changes in interest rates. Additionally, the Company may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, forward sale commitments, or mortgage interest rate lock commitments, to mitigate the Company's exposure to interest rate risk. The Company does not hedge all of its commodity price, interest rate and foreign currency exchange rate risks, thereby exposing the unhedged portion to changes in market prices. There have been no significant changes in the Company's accounting policies related to derivatives. Refer to Notes 2 , 6 and 15 for additional information on derivative contracts. The following table, which reflects master netting arrangements and excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of the Company's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Consolidated Balance Sheets (in millions): Other Other Other Current Other Current Long-term Assets Assets Liabilities Liabilities Total As of December 31, 2016: Not designated as hedging contracts: Commodity assets (1) $ 42 $ 86 $ 5 $ 2 $ 135 Commodity liabilities (1) (10 ) — (46 ) (150 ) (206 ) Interest rate assets 15 — — — 15 Interest rate liabilities — — (4 ) (6 ) (10 ) Total 47 86 (45 ) (154 ) (66 ) Designated as hedging contracts: Commodity assets 1 — 2 3 6 Commodity liabilities — — (14 ) (8 ) (22 ) Interest rate assets — 8 — — 8 Interest rate liabilities — — (3 ) — (3 ) Total 1 8 (15 ) (5 ) (11 ) Total derivatives 48 94 (60 ) (159 ) (77 ) Cash collateral receivable — — 13 61 74 Total derivatives - net basis $ 48 $ 94 $ (47 ) $ (98 ) $ (3 ) As of December 31, 2015: Not designated as hedging contracts: Commodity assets (1) $ 25 $ 72 $ 7 $ 2 $ 106 Commodity liabilities (1) (4 ) — (113 ) (175 ) (292 ) Interest rate assets 7 — — — 7 Interest rate liabilities — — (3 ) (6 ) (9 ) Total 28 72 (109 ) (179 ) (188 ) Designated as hedging contracts: Commodity assets — — 1 2 3 Commodity liabilities — — (33 ) (17 ) (50 ) Interest rate assets — 3 — — 3 Interest rate liabilities — — (4 ) (1 ) (5 ) Total — 3 (36 ) (16 ) (49 ) Total derivatives 28 75 (145 ) (195 ) (237 ) Cash collateral receivable — — 40 63 103 Total derivatives - net basis $ 28 $ 75 $ (105 ) $ (132 ) $ (134 ) (1) The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31, 2016 and 2015 , a net regulatory asset of $148 million and $250 million , respectively, was recorded related to the net derivative liability of $71 million and $186 million , respectively. The difference between the net regulatory asset and the net derivative liability relates primarily to a power purchase agreement derivative at BHE Renewables. Not Designated as Hedging Contracts The following table reconciles the beginning and ending balances of the Company's net regulatory assets and summarizes the pre-tax gains and losses on commodity derivative contracts recognized in net regulatory assets, as well as amounts reclassified to earnings for the years ended December 31 (in millions): Commodity Derivatives 2016 2015 2014 Beginning balance $ 250 $ 223 $ 182 Changes in fair value recognized in net regulatory assets (30 ) 128 96 Net (losses) gains reclassified to operating revenue (5 ) 1 (32 ) Net losses reclassified to cost of sales (67 ) (102 ) (23 ) Ending balance $ 148 $ 250 $ 223 Designated as Hedging Contracts The Company uses commodity derivative contracts accounted for as cash flow hedges to hedge electricity and natural gas commodity prices for delivery to nonregulated customers, spring operational sales, natural gas storage and other transactions. Certain commodity derivative contracts have settled and the fair value at the date of settlement remains in AOCI and is recognized in earnings when the forecasted transactions impact earnings. The following table reconciles the beginning and ending balances of the Company's AOCI (pre-tax) and summarizes pre-tax gains and losses on commodity derivative contracts designated and qualifying as cash flow hedges recognized in OCI, as well as amounts reclassified to earnings for the years ended December 31 (in millions): Commodity Derivatives 2016 2015 2014 Beginning balance $ 46 $ 32 $ 12 Changes in fair value recognized in OCI 26 52 (6 ) Net gains reclassified to operating revenue 1 9 — Net (losses) gains reclassified to cost of sales (57 ) (47 ) 26 Ending balance $ 16 $ 46 $ 32 Realized gains and losses on hedges and hedge ineffectiveness are recognized in income as operating revenue, cost of sales, operating expense or interest expense depending upon the nature of the item being hedged. For the years ended December 31, 2016 , 2015 and 2014 , hedge ineffectiveness was insignificant . As of December 31, 2016 , the Company had cash flow hedges with expiration dates extending through June 2026 and $14 million of pre-tax unrealized losses are forecasted to be reclassified from AOCI into earnings over the next twelve months as contracts settle. Derivative Contract Volumes The following table summarizes the net notional amounts of outstanding derivative contracts with fixed price terms that comprise the mark-to-market values as of December 31 (in millions): Unit of Measure 2016 2015 Electricity purchases Megawatt hours 5 10 Natural gas purchases Decatherms 271 317 Fuel purchases Gallons 11 11 Interest rate swaps US$ 714 653 Mortgage commitments, net US$ (309 ) (312 ) Credit Risk The Utilities are exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent the Utilities' counterparties have similar economic, industry or other characteristics and due to direct or indirect relationships among the counterparties. Before entering into a transaction, the Utilities analyze the financial condition of each significant wholesale counterparty, establish limits on the amount of unsecured credit to be extended to each counterparty and evaluate the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, the Utilities enter into netting and collateral arrangements that may include margining and cross-product netting agreements and obtain third-party guarantees, letters of credit and cash deposits. If required, the Utilities exercise rights under these arrangements, including calling on the counterparty's credit support arrangement. Collateral and Contingent Features In accordance with industry practice, certain wholesale derivative contracts contain credit support provisions that in part base certain collateral requirements on credit ratings for senior unsecured debt as reported by one or more of the three recognized credit rating agencies. These derivative contracts may either specifically provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels ("credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance," or in some cases terminate the contract, in the event of a material adverse change in creditworthiness. These rights can vary by contract and by counterparty. As of December 31, 2016 , the applicable credit ratings from the three recognized credit rating agencies were investment grade. The aggregate fair value of the Company's derivative contracts in liability positions with specific credit-risk-related contingent features totaled $190 million and $288 million as of December 31, 2016 and 2015 , respectively, for which the Company had posted collateral of $69 million and $75 million , respectively, in the form of cash deposits. If all credit-risk-related contingent features for derivative contracts in liability positions had been triggered as of December 31, 2016 and 2015 , the Company would have been required to post $110 million and $198 million , respectively, of additional collateral. The Company's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation, or other factors.
PacifiCorp [Member]
Derivative [Line Items]
Risk Management and Hedging Activities [Text Block]	Risk Management and Hedging Activities PacifiCorp is exposed to the impact of market fluctuations in commodity prices and interest rates. PacifiCorp is principally exposed to electricity, natural gas, coal and fuel oil commodity price risk as it has an obligation to serve retail customer load in its service territories. PacifiCorp's load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity and wholesale electricity that is purchased and sold. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather, market liquidity, generating facility availability, customer usage, storage, and transmission and transportation constraints. Interest rate risk exists on variable-rate debt and future debt issuances. PacifiCorp does not engage in a material amount of proprietary trading activities. PacifiCorp has established a risk management process that is designed to identify, assess, manage, mitigate, monitor and report, each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, PacifiCorp uses commodity derivative contracts, which may include forwards, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. PacifiCorp manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed-rate long-term debt and by monitoring market changes in interest rates. Additionally, PacifiCorp may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, to mitigate PacifiCorp's exposure to interest rate risk. No interest rate derivatives were in place during the periods presented. PacifiCorp does not hedge all of its commodity price and interest rate risks, thereby exposing the unhedged portion to changes in market prices. There have been no significant changes in PacifiCorp's accounting policies related to derivatives. Refer to Notes 2 and 12 for additional information on derivative contracts. The following table, which reflects master netting arrangements and excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of PacifiCorp's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Consolidated Balance Sheets (in millions): Other Other Other Current Other Current Long-term Assets Assets Liabilities Liabilities Total As of December 31, 2016: Not designated as hedging contracts (1) : Commodity assets $ 24 $ 2 $ 1 $ — $ 27 Commodity liabilities (6 ) — (14 ) (84 ) (104 ) Total 18 2 (13 ) (84 ) (77 ) Total derivatives 18 2 (13 ) (84 ) (77 ) Cash collateral receivable — — 10 59 69 Total derivatives - net basis $ 18 $ 2 $ (3 ) $ (25 ) $ (8 ) As of December 31, 2015: Not designated as hedging contracts (1) : Commodity assets $ 10 $ — $ 2 $ — $ 12 Commodity liabilities (1 ) — (58 ) (89 ) (148 ) Total 9 — (56 ) (89 ) (136 ) Total derivatives 9 — (56 ) (89 ) (136 ) Cash collateral receivable — — 18 57 75 Total derivatives - net basis $ 9 $ — $ (38 ) $ (32 ) $ (61 ) (1) PacifiCorp's commodity derivatives are generally included in rates and as of December 31, 2016 and 2015 , a regulatory asset of $73 million and $133 million , respectively, was recorded related to the net derivative liability of $77 million and $136 million , respectively. The following table reconciles the beginning and ending balances of PacifiCorp's regulatory assets and summarizes the pre-tax gains and losses on commodity derivative contracts recognized in regulatory assets, as well as amounts reclassified to earnings for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 133 $ 85 $ 55 Changes in fair value recognized in regulatory assets (27 ) 82 45 Net gains reclassified to operating revenue 10 40 (4 ) Net losses reclassified to energy costs (43 ) (74 ) (11 ) Ending balance $ 73 $ 133 $ 85 Derivative Contract Volumes The following table summarizes the net notional amounts of outstanding commodity derivative contracts with fixed price terms that comprise the mark-to-market values as of December 31 (in millions): Unit of Measure 2016 2015 Electricity (sales) purchases Megawatt hours (3 ) 1 Natural gas purchases Decatherms 84 111 Fuel oil purchases Gallons 11 11 Credit Risk PacifiCorp is exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent PacifiCorp's counterparties have similar economic, industry or other characteristics and due to direct or indirect relationships among the counterparties. Before entering into a transaction, PacifiCorp analyzes the financial condition of each significant wholesale counterparty, establishes limits on the amount of unsecured credit to be extended to each counterparty and evaluates the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, PacifiCorp enters into netting and collateral arrangements that may include margining and cross-product netting agreements and obtains third-party guarantees, letters of credit and cash deposits. If required, PacifiCorp exercises rights under these arrangements, including calling on the counterparty's credit support arrangement. Collateral and Contingent Features In accordance with industry practice, certain wholesale derivative contracts contain credit support provisions that in part base certain collateral requirements on credit ratings for senior unsecured debt as reported by one or more of the three recognized credit rating agencies. These derivative contracts may either specifically provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels ("credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance" in the event of a material adverse change in PacifiCorp's creditworthiness. These rights can vary by contract and by counterparty. As of December 31, 2016 , PacifiCorp's credit ratings from the three recognized credit rating agencies were investment grade. The aggregate fair value of PacifiCorp's derivative contracts in liability positions with specific credit-risk-related contingent features totaled $97 million and $142 million as of December 31, 2016 and 2015 , respectively, for which PacifiCorp had posted collateral of $69 million and $75 million , respectively, in the form of cash deposits. If all credit-risk-related contingent features for derivative contracts in liability positions had been triggered as of December 31, 2016 and 2015 , PacifiCorp would have been required to post $22 million and $64 million , respectively, of additional collateral. PacifiCorp's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation or other factors.
MidAmerican Energy Company [Member]
Derivative [Line Items]
Risk Management and Hedging Activities [Text Block]	Risk Management and Hedging Activities MidAmerican Energy is exposed to the impact of market fluctuations in commodity prices and interest rates. MidAmerican Energy is principally exposed to electricity, natural gas, coal and fuel oil commodity price risk as it has an obligation to serve retail customer load in its regulated service territory. Prior to January 1, 2016, MidAmerican Energy also provided nonregulated retail electricity and natural gas services in competitive markets, which created contractual obligations to provide electric and natural gas services. MidAmerican Energy's load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity, wholesale electricity that is purchased and sold, and natural gas supply for retail customers. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather; market liquidity; generating facility availability; customer usage; storage; and transmission and transportation constraints. Interest rate risk exists on variable-rate debt and future debt issuances. MidAmerican Energy does not engage in a material amount of proprietary trading activities. MidAmerican Energy has established a risk management process that is designed to identify, assess, monitor, report, manage and mitigate each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, MidAmerican Energy uses commodity derivative contracts, which may include forwards, futures, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. MidAmerican Energy manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed-rate long-term debt and by monitoring market changes in interest rates. Additionally, MidAmerican Energy may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, to mitigate its exposure to interest rate risk. MidAmerican Energy does not hedge all of its commodity price and interest rate risks, thereby exposing the unhedged portion to changes in market prices. There have been no significant changes in MidAmerican Energy's accounting policies related to derivatives. Refer to Notes 2 and 14 for additional information on derivative contracts and to Note 3 for a discussion of discontinued operations. The following table, which reflects master netting arrangements and excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of MidAmerican Energy's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Balance Sheets (in millions): Other Other Other Current Other Current Long-term Assets Assets Liabilities Liabilities Total As of December 31, 2016: Not designated as hedging contracts (1)(2) : Commodity assets $ 8 $ 2 $ — $ — $ 10 Commodity liabilities (2 ) — (3 ) (1 ) (6 ) Total 6 2 (3 ) (1 ) 4 Designated as hedging contracts (2) : Commodity assets — — — — — Commodity liabilities — — — — — Total — — — — — Total derivatives 6 2 (3 ) (1 ) 4 Cash collateral receivable — — 1 — 1 Total derivatives - net basis $ 6 $ 2 $ (2 ) $ (1 ) $ 5 As of December 31, 2015: Not designated as hedging contracts (1) : Commodity assets $ 12 $ 4 $ 5 $ 2 $ 23 Commodity liabilities (3 ) — (36 ) (10 ) (49 ) Total 9 4 (31 ) (8 ) (26 ) Designated as hedging contracts: Commodity assets — — 1 2 3 Commodity liabilities — — (32 ) (17 ) (49 ) Total — — (31 ) (15 ) (46 ) Total derivatives 9 4 (62 ) (23 ) (72 ) Cash collateral receivable — — 22 6 28 Total derivatives - net basis $ 9 $ 4 $ (40 ) $ (17 ) $ (44 ) (1) MidAmerican Energy's commodity derivatives not designated as hedging contracts are generally included in regulated rates. Accordingly, as of December 31, 2016 , a net regulatory liability of $4 million was recorded related to the net derivative asset of $4 million , and as of December 31, 2015 , a net regulatory asset of $20 million was recorded related to the net derivative liability of $26 million . (2) The changes in derivative values from December 31, 2015, are substantially due to the transfer of MidAmerican Energy's unregulated retail services business to a subsidiary of BHE. Not Designated as Hedging Contracts The following table reconciles the beginning and ending balances of MidAmerican Energy's net regulatory assets (liabilities) and summarizes the pre-tax gains and losses on commodity derivative contracts recognized in net regulatory assets (liabilities), as well as amounts reclassified to earnings for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 20 $ 38 $ 10 Changes in fair value recognized in net regulatory assets (liabilities) 3 40 61 Net losses reclassified to operating revenue (15 ) (42 ) (28 ) Net losses reclassified to cost of fuel, energy and capacity — (1 ) (1 ) Net losses reclassified to cost of gas sold (12 ) (15 ) (4 ) Ending balance $ (4 ) $ 20 $ 38 The following table summarizes the pre-tax unrealized gains (losses) included on the Statements of Operations associated with MidAmerican Energy's derivative contracts not designated as hedging contracts and not recorded as a net regulatory asset or liability for the years ended December 31 (in millions): 2016 2015 2014 Nonregulated operating revenue $ — $ 15 $ 6 Regulated cost of fuel, energy and capacity — 2 — Nonregulated cost of sales — (21 ) 9 Total $ — $ (4 ) $ 15 Designated as Hedging Contracts MidAmerican Energy used derivative contracts accounted for as cash flow hedges to hedge electricity and natural gas commodity prices related to its unregulated retail services business, which was transferred to a subsidiary of BHE. The following table reconciles the beginning and ending balances of MidAmerican Energy's accumulated other comprehensive loss (pre-tax) and summarizes pre-tax gains and losses on derivative contracts designated and qualifying as cash flow hedges recognized in OCI, as well as amounts reclassified to earnings, for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 45 $ 34 $ 11 Transfer to affiliate (45 ) — — Changes in fair value recognized in OCI — 58 (3 ) Net (losses) gains reclassified to nonregulated cost of sales — (47 ) 26 Ending balance $ — $ 45 $ 34 Derivative Contract Volumes The following table summarizes the net notional amounts of outstanding derivative contracts with fixed price terms that comprise the mark-to-market values as of December 31 (in millions): Unit of Measure 2016 2015 Electricity purchases Megawatt hours — 15 Natural gas purchases Decatherms 18 17 Credit Risk MidAmerican Energy is exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Additionally, MidAmerican Energy participates in the regional transmission organization ("RTO") markets and has indirect credit exposure related to other participants, although RTO credit policies are designed to limit exposure to credit losses from individual participants. Credit risk may be concentrated to the extent MidAmerican Energy's counterparties have similar economic, industry or other characteristics and due to direct or indirect relationships among the counterparties. Before entering into a transaction, MidAmerican Energy analyzes the financial condition of each significant wholesale counterparty, establishes limits on the amount of unsecured credit to be extended to each counterparty, and evaluates the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, MidAmerican Energy enters into netting and collateral arrangements that may include margining and cross-product netting agreements and obtains third-party guarantees, letters of credit and cash deposits. If required, MidAmerican Energy exercises rights under these arrangements, including calling on the counterparty's credit support arrangement. Collateral and Contingent Features In accordance with industry practice, certain wholesale derivative contracts contain credit support provisions that in part base MidAmerican Energy's collateral requirements on its credit ratings for senior unsecured debt as reported by one or more of the three recognized credit rating agencies. These derivative contracts may either specifically provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels ("credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance," or in some cases terminate the contract, in the event of a material adverse change in MidAmerican Energy's creditworthiness. These rights can vary by contract and by counterparty. As of December 31, 2016 , MidAmerican Energy's credit ratings from the three recognized credit rating agencies were investment grade. The aggregate fair value of MidAmerican Energy's derivative contracts in liability positions with specific credit-risk-related contingent features totaled $3 million and $66 million as of December 31, 2016 and 2015 , respectively, for which MidAmerican Energy had posted collateral of $- million at each date. If all credit-risk-related contingent features for derivative contracts in liability positions had been triggered as of December 31, 2016 and 2015 , MidAmerican Energy would have been required to post $2 million and $55 million , respectively, of additional collateral. MidAmerican Energy's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation, or other factors. MidAmerican Energy's exposure to contingent features declined significantly as a result of the transfer of its unregulated retail services business to a subsidiary of BHE.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Derivative [Line Items]
Risk Management and Hedging Activities [Text Block]	Risk Management and Hedging Activities Refer to Note 13 of MidAmerican Energy's Notes to Financial Statements.
Nevada Power Company [Member]
Derivative [Line Items]
Risk Management and Hedging Activities [Text Block]	Risk Management and Hedging Activities Nevada Power is exposed to the impact of market fluctuations in commodity prices and interest rates. Nevada Power is principally exposed to electricity, natural gas and coal market fluctuations primarily through Nevada Power 's obligation to serve retail customer load in its regulated service territory. Nevada Power 's load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity and wholesale electricity that is purchased and sold. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather, market liquidity, generating facility availability, customer usage, storage, and transmission and transportation constraints. The actual cost of fuel and purchased power is recoverable through the deferred energy mechanism. Interest rate risk exists on variable-rate debt and future debt issuances. Nevada Power does not engage in proprietary trading activities. Nevada Power has established a risk management process that is designed to identify, assess, manage, mitigate, monitor and report each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, Nevada Power uses commodity derivative contracts, which may include forwards, futures, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. Nevada Power manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed‑rate long-term debt and by monitoring market changes in interest rates. Additionally, Nevada Power may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, to mitigate Nevada Power 's exposure to interest rate risk. Nevada Power does not hedge all of its commodity price and interest rate risks, thereby exposing the unhedged portion to changes in market prices. There have been no significant changes in Nevada Power 's accounting policies related to derivatives. Refer to Notes 2 and 9 for additional information on derivative contracts. The following table, which excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of Nevada Power 's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Consolidated Balance Sheets (in millions): Other Other Current Long-term Liabilities Liabilities Total As of December 31, 2016: Commodity derivative liabilities (1) $ (7 ) $ (7 ) $ (14 ) As of December 31, 2015: Commodity derivative liabilities (1) $ (8 ) $ (14 ) $ (22 ) (1) Nevada Power 's commodity derivatives not designated as hedging contracts are included in regulated rates and as of December 31 , 2016 and 2015 , a regulatory asset of $14 million and $22 million , respectively, was recorded related to the derivative liability of $14 million and $22 million , respectively. Derivative Contract Volumes The following table summarizes the net notional amounts of outstanding derivative contracts with indexed and fixed price terms that comprise the mark-to-market values as of December 31 (in millions): Unit of Measure 2016 2015 Electricity sales Megawatt hours (2 ) (2 ) Natural gas purchases Decatherms 114 126 Credit Risk Nevada Power is exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent Nevada Power 's counterparties have similar economic, industry or other characteristics and due to direct and indirect relationships among the counterparties. Before entering into a transaction, Nevada Power analyzes the financial condition of each significant wholesale counterparty, establish limits on the amount of unsecured credit to be extended to each counterparty and evaluate the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, Nevada Power enters into netting and collateral arrangements that may include margining and cross-product netting agreements and obtain third-party guarantees, letters of credit and cash deposits. If required, Nevada Power exercises rights under these arrangements, including calling on the counterparty's credit support arrangement. Collateral and Contingent Features In accordance with industry practice, certain wholesale derivative contracts contain credit support provisions that in part base certain collateral requirements on credit ratings for unsecured debt as reported by one or more of the three recognized credit rating agencies. These derivative contracts may either specifically provide rights to demand cash or other security in the event of a credit rating downgrade ("credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance," in the event of a material adverse change in creditworthiness. These rights can vary by contract and by counterparty. As of December 31, 2016 , credit ratings from the three recognized credit rating agencies were investment grade. The aggregate fair value of Nevada Power 's derivative contracts in liability positions with specific credit-risk-related contingent features was $2 million and $3 million as of December 31, 2016 and 2015 , respectively, which represents the amount of collateral to be posted if all credit risk related contingent features for derivative contracts in liability positions had been triggered. Nevada Power 's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation or other factors.

Fair Value Measurements (Notes)

Fair Value Measurements (Notes)	12 Months Ended
	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements [Text Block]	Fair Value Measurements The carrying value of the Company's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. The Company has various financial assets and liabilities that are measured at fair value on the Consolidated Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows: • Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date. • Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs). • Level 3 - Unobservable inputs reflect the Company's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. The Company develops these inputs based on the best information available, including its own data. The following table presents the Company's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Other (1) Total As of December 31, 2016: Assets: Commodity derivatives $ 5 $ 49 $ 87 $ (22 ) $ 119 Interest rate derivatives — 16 7 — 23 Mortgage loans held for sale — 359 — — 359 Money market mutual funds (2) 586 — — — 586 Debt securities: United States government obligations 161 — — — 161 International government obligations — 3 — — 3 Corporate obligations — 36 — — 36 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Equity securities: United States companies 250 — — — 250 International companies 1,190 — — — 1,190 Investment funds 147 — — — 147 $ 2,339 $ 467 $ 94 $ (22 ) $ 2,878 Liabilities: Commodity derivatives $ (2 ) $ (199 ) $ (27 ) $ 96 $ (132 ) Interest rate derivatives (1 ) (11 ) (1 ) — (13 ) $ (3 ) $ (210 ) $ (28 ) $ 96 $ (145 ) As of December 31, 2015: Assets: Commodity derivatives $ — $ 16 $ 93 $ (16 ) $ 93 Interest rate derivatives — 5 5 — 10 Mortgage loans held for sale — 327 — — 327 Money market mutual funds (2) 421 — — — 421 Debt securities: United States government obligations 133 — — — 133 International government obligations — 2 — — 2 Corporate obligations — 39 — — 39 Municipal obligations — 1 — — 1 Agency, asset and mortgage-backed obligations — 3 — — 3 Auction rate securities — — 44 — 44 Equity securities: United States companies 239 — — — 239 International companies 1,244 — — — 1,244 Investment funds 136 — — — 136 $ 2,173 $ 393 $ 142 $ (16 ) $ 2,692 Liabilities: Commodity derivatives $ (13 ) $ (283 ) $ (46 ) $ 119 $ (223 ) Interest rate derivatives — (13 ) (1 ) — (14 ) $ (13 ) $ (296 ) $ (47 ) $ 119 $ (237 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $74 million and $103 million as of December 31, 2016 and 2015 , respectively. (2) Amounts are included in cash and cash equivalents; other current assets; and noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which the Company transacts. When quoted prices for identical contracts are not available, the Company uses forward price curves. Forward price curves represent the Company's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. The Company bases its forward price curves upon market price quotations, when available, or internally developed and commercial models, with internal and external fundamental data inputs. Market price quotations are obtained from independent brokers, exchanges, direct communication with market participants and actual transactions executed by the Company. Market price quotations are generally readily obtainable for the applicable term of the Company's outstanding derivative contracts; therefore, the Company's forward price curves reflect observable market quotes. Market price quotations for certain electricity and natural gas trading hubs are not as readily obtainable due to the length of the contract. Given that limited market data exists for these contracts, as well as for those contracts that are not actively traded, the Company uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The estimated fair value of these derivative contracts is a function of underlying forward commodity prices, interest rates, currency rates, related volatility, counterparty creditworthiness and duration of contracts. Refer to Note 14 for further discussion regarding the Company's risk management and hedging activities. The Company's mortgage loans held for sale are valued based on independent quoted market prices, where available, or the prices of other mortgage whole loans with similar characteristics. As necessary, these prices are adjusted for typical securitization activities, including servicing value, portfolio composition, market conditions and liquidity. The Company's investments in money market mutual funds and debt and equity securities are stated at fair value and are primarily accounted for as available-for-sale securities. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. In the absence of a quoted market price or net asset value of an identical security, the fair value is determined using pricing models or net asset values based on observable market inputs and quoted market prices of securities with similar characteristics. The fair value of the Company's investments in auction rate securities was determined using pricing models based on available observable market data and the Company's judgment about the assumptions, including liquidity and nonperformance risks, which market participants would use when pricing the asset. The following table reconciles the beginning and ending balances of the Company's assets and liabilities measured at fair value on a recurring basis using significant Level 3 inputs for the years ended December 31 (in millions): Commodity Derivatives Interest Rate Derivatives Auction Rate Securities 2016 2015 2014 2016 2015 2014 2016 2015 2014 Beginning balance $ 47 $ 51 $ 60 $ 4 $ — $ — $ 44 $ 45 $ 44 Changes included in earnings 8 19 19 121 87 — 5 — — Changes in fair value recognized in OCI (2 ) (7 ) — — — — 8 (1 ) 1 Changes in fair value recognized in net regulatory assets (11 ) (19 ) 5 — — — — — — Purchases 1 1 1 — — — — — — Redemptions — — — — — — (57 ) — — Settlements 17 2 1 (119 ) (86 ) — — — — Transfers from Level 2 — — (35 ) — 3 — — — — Ending balance $ 60 $ 47 $ 51 $ 6 $ 4 $ — $ — $ 44 $ 45 The Company's long-term debt is carried at cost on the Consolidated Financial Statements. The fair value of the Company's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of the Company's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of the Company's long-term debt as of December 31 (in millions): 2016 2015 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 36,116 $ 40,718 $ 37,972 $ 41,785
PacifiCorp [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements [Text Block]	Fair Value Measurements The carrying value of PacifiCorp's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. PacifiCorp has various financial assets and liabilities that are measured at fair value on the Consolidated Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows: • Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that PacifiCorp has the ability to access at the measurement date. • Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs). • Level 3 - Unobservable inputs reflect PacifiCorp's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. PacifiCorp develops these inputs based on the best information available, including its own data. The following table presents PacifiCorp's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Other (1) Total As of December 31, 2016: Assets: Commodity derivatives $ — $ 27 $ — $ (7 ) $ 20 Money market mutual funds (2) 13 — — — 13 Investment funds 17 — — — 17 $ 30 $ 27 $ — $ (7 ) $ 50 Liabilities - Commodity derivatives $ — $ (104 ) $ — $ 76 $ (28 ) As of December 31, 2015: Assets: Commodity derivatives $ — $ 9 $ 3 $ (3 ) $ 9 Money market mutual funds (2) 13 — — — 13 Investment funds 15 — — — 15 $ 28 $ 9 $ 3 $ (3 ) $ 37 Liabilities - Commodity derivatives $ — $ (148 ) $ — $ 78 $ (70 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $69 million and $75 million as of December 31, 2016 and 2015 , respectively. (2) Amounts are included in cash and cash equivalents, other current assets and other assets on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which PacifiCorp transacts. When quoted prices for identical contracts are not available, PacifiCorp uses forward price curves. Forward price curves represent PacifiCorp's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. PacifiCorp bases its forward price curves upon market price quotations, when available, or internally developed and commercial models, with internal and external fundamental data inputs. Market price quotations are obtained from independent energy brokers, exchanges, direct communication with market participants and actual transactions executed by PacifiCorp. Market price quotations for certain major electricity and natural gas trading hubs are generally readily obtainable for the first six years; therefore, PacifiCorp's forward price curves for those locations and periods reflect observable market quotes. Market price quotations for other electricity and natural gas trading hubs are not as readily obtainable for the first six years. Given that limited market data exists for these contracts, as well as for those contracts that are not actively traded, PacifiCorp uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The estimated fair value of these derivative contracts is a function of underlying forward commodity prices, interest rates, currency rates, related volatility, counterparty creditworthiness and duration of contracts. Refer to Note 11 for further discussion regarding PacifiCorp's risk management and hedging activities. PacifiCorp's investments in money market mutual funds and investment funds are stated at fair value and are primarily accounted for as available-for-sale securities. When available, PacifiCorp uses a readily observable quoted market price or net asset value of an identical security in an active market to record the fair value. In the absence of a quoted market price or net asset value of an identical security, the fair value is determined using pricing models or net asset values based on observable market inputs and quoted market prices of securities with similar characteristics. PacifiCorp's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of PacifiCorp's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of PacifiCorp's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of PacifiCorp's long-term debt as of December 31 (in millions): 2016 2015 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 7,052 $ 8,204 $ 7,114 $ 8,210
MidAmerican Energy Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements [Text Block]	Fair Value Measurements The carrying value of MidAmerican Energy's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. MidAmerican Energy has various financial assets and liabilities that are measured at fair value on the Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows: • Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that MidAmerican Energy has the ability to access at the measurement date. • Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs). • Level 3 - Unobservable inputs reflect MidAmerican Energy's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. MidAmerican Energy develops these inputs based on the best information available, including its own data. The following table presents MidAmerican Energy's assets and liabilities recognized on the Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Other (1) Total As of December 31, 2016: Assets: Commodity derivatives $ — $ 9 $ 1 $ (2 ) $ 8 Money market mutual funds (2) 1 — — — 1 Debt securities: United States government obligations 161 — — — 161 International government obligations — 3 — — 3 Corporate obligations — 36 — — 36 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Equity securities: United States companies 250 — — — 250 International companies 5 — — — 5 Investment funds 9 — — — 9 $ 426 $ 52 $ 1 $ (2 ) $ 477 Liabilities - commodity derivatives $ — $ (3 ) $ (3 ) $ 3 $ (3 ) As of December 31, 2015 Assets: Commodity derivatives $ — $ 8 $ 18 $ (13 ) $ 13 Money market mutual funds (2) 56 — — — 56 Debt securities: United States government obligations 133 — — — 133 International government obligations — 2 — — 2 Corporate obligations — 39 — — 39 Municipal obligations — 1 — — 1 Agency, asset and mortgage-backed obligations — 3 — — 3 Auction rate securities — — 26 — 26 Equity securities: United States companies 239 — — — 239 International companies 6 — — — 6 Investment funds 4 — — — 4 $ 438 $ 53 $ 44 $ (13 ) $ 522 Liabilities - commodity derivatives $ (13 ) $ (61 ) $ (24 ) $ 41 $ (57 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $1 million and $28 million as of December 31, 2016 and 2015 , respectively. (2) Amounts are included in cash and cash equivalents and investments and restricted cash and investments on the Balance Sheets. The fair value of these money market mutual funds approximates cost. Derivative contracts are recorded on the Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which MidAmerican Energy transacts. When quoted prices for identical contracts are not available, MidAmerican Energy uses forward price curves. Forward price curves represent MidAmerican Energy's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. MidAmerican Energy bases its forward price curves upon market price quotations, when available, or internally developed and commercial models, with internal and external fundamental data inputs. Market price quotations are obtained from independent energy brokers, exchanges, direct communication with market participants and actual transactions executed by MidAmerican Energy. Market price quotations are generally readily obtainable for the applicable term of MidAmerican Energy's outstanding derivative contracts; therefore, MidAmerican Energy's forward price curves reflect observable market quotes. Market price quotations for certain electricity and natural gas trading hubs are not as readily obtainable due to the length of the contract. Given that limited market data exists for these contracts, as well as for those contracts that are not actively traded, MidAmerican Energy uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The estimated fair value of these derivative contracts is a function of underlying forward commodity prices, interest rates, related volatility, counterparty creditworthiness and duration of contracts. Refer to Note 13 for further discussion regarding MidAmerican Energy's risk management and hedging activities. MidAmerican Energy's investments in money market mutual funds and debt and equity securities are stated at fair value and are primarily accounted for as available-for-sale securities. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. In the absence of a quoted market price or net asset value of an identical security, the fair value is determined using pricing models or net asset values based on observable market inputs and quoted market prices of securities with similar characteristics. The fair value of MidAmerican Energy's investments in auction rate securities, where there is no current liquid market, is determined using pricing models based on available observable market data and MidAmerican Energy's judgment about the assumptions, including liquidity and nonperformance risks, which market participants would use when pricing the asset. The auction rate securities were fully redeemed at par value in 2016. The following table reconciles the beginning and ending balances of MidAmerican Energy's assets measured at fair value on a recurring basis using significant Level 3 inputs for the years ended December 31 (in millions): Commodity Derivatives Auction Rate Securities 2016 2015 2014 2016 2015 2014 Beginning balance $ (6 ) $ 12 $ (3 ) $ 26 $ 26 $ 23 Transfer to affiliate (4 ) — — — — — Changes included in earnings (1) — 11 12 5 — — Changes in fair value recognized in OCI — (7 ) — 4 — 3 Changes in fair value recognized in net regulatory assets (6 ) (25 ) 6 — — — Purchases — 1 1 — — — Redemptions — — — (35 ) — — Settlements 14 2 (4 ) — — — Ending balance $ (2 ) $ (6 ) $ 12 $ — $ 26 $ 26 (1) Changes included in earnings related to MidAmerican Energy's unregulated retail services business that was transferred to an affiliate of BHE. Refer to Note 3 for a discussion of discontinued operations. Net unrealized (losses) gains included in earnings for the years ended December 31, 2015 and 2014 , related to commodity derivatives held at December 31, 2015 and 2014 , totaled $8 million and $16 million , respectively. MidAmerican Energy's long-term debt is carried at cost on the Financial Statements. The fair value of MidAmerican Energy's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of MidAmerican Energy's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of MidAmerican Energy's long-term debt as of December 31, (in millions): 2016 2015 Carrying Value Fair Value Carrying Value Fair Value Long-term debt $ 4,301 $ 4,735 $ 4,271 $ 4,636
MidAmerican Funding, LLC and Subsidiaries [Domain]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements [Text Block]	Fair Value Measurements Refer to Note 14 of MidAmerican Energy's Notes to Financial Statements. MidAmerican Funding's long-term debt is carried at cost on the Consolidated Financial Statements. The fair value of MidAmerican Funding's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of MidAmerican Funding's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of MidAmerican Funding's long-term debt as of December 31 (in millions): 2016 2015 Carrying Value Fair Value Carrying Value Fair Value Long-term debt $ 4,627 $ 5,164 $ 4,597 $ 5,051
Nevada Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements [Text Block]	Fair Value Measurements The carrying value of Nevada Power 's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. Nevada Power has various financial assets and liabilities that are measured at fair value on the Consolidated Balance Sheets using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows: • Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that Nevada Power has the ability to access at the measurement date. • Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs). • Level 3 - Unobservable inputs reflect Nevada Power 's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. Nevada Power develops these inputs based on the best information available, including its own data. The following table presents Nevada Power 's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Total As of December 31, 2016: Assets: Money market mutual funds (1) $ 220 $ — $ — $ 220 Investment funds 6 — — 6 $ 226 $ — $ — $ 226 Liabilities - commodity derivatives $ — $ — $ (14 ) $ (14 ) As of December 31, 2015: Assets - investment funds $ 5 $ — $ — $ 5 Liabilities - commodity derivatives $ — $ — $ (22 ) $ (22 ) (1) Amounts are included in cash and cash equivalents on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which Nevada Power transacts. When quoted prices for identical contracts are not available, Nevada Power uses forward price curves. Forward price curves represent Nevada Power 's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. Nevada Power bases its forward price curves upon internally developed models, with internal and external fundamental data inputs. Market price quotations for certain electricity and natural gas trading hubs are not as readily obtainable due to markets that are not active. Given that limited market data exists for these contracts, Nevada Power uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The model incorporates a mid-market pricing convention (the mid‑point price between bid and ask prices) as a practical expedient for valuing its assets and liabilities measured and reported at fair value. The determination of the fair value for derivative contracts not only includes counterparty risk, but also the impact of Nevada Power 's nonperformance risk on its liabilities, which as of December 31, 2016 , had an immaterial impact to the fair value of its derivative contracts. As such, Nevada Power considers its derivative contracts to be valued using Level 3 inputs. Refer to Note 8 for further discussion regarding Nevada Power 's risk management and hedging activities. Nevada Power 's investments in money market mutual funds and equity securities are accounted for as available-for-sale securities and are stated at fair value. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. The following table reconciles the beginning and ending balances of Nevada Power 's commodity derivative liabilities measured at fair value on a recurring basis using significant Level 3 inputs for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ (22 ) $ (30 ) $ (47 ) Changes in fair value recognized in regulatory assets (4 ) — 9 Settlements 12 8 8 Ending balance $ (14 ) $ (22 ) $ (30 ) Nevada Power 's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of Nevada Power 's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of Nevada Power 's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of Nevada Power 's long-term debt as of December 31 (in millions): 2016 2015 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 2,581 $ 3,040 $ 2,788 $ 3,240
Sierra Pacific Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements [Text Block]	Fair Value Measurements The carrying value of Sierra Pacific 's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. Sierra Pacific has various financial assets and liabilities that are measured at fair value on the Consolidated Balance Sheets using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows: • Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that Sierra Pacific has the ability to access at the measurement date. • Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs). • Level 3 - Unobservable inputs reflect Sierra Pacific 's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. Sierra Pacific develops these inputs based on the best information available, including its own data. The following table presents Sierra Pacific 's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Total As of December 31, 2016: Assets: Money market mutual funds (1) $ 35 $ — $ — $ 35 Investment funds 1 — — 1 $ 36 $ — $ — $ 36 As of December 31, 2015: Assets - investment funds $ 1 $ — $ — $ 1 Liabilities - commodity derivatives $ — $ — $ (1 ) $ (1 ) (1) Amounts are included in cash and cash equivalents on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost. Sierra Pacific 's investments in money market mutual funds and equity securities are accounted for as available-for-sale securities and are stated at fair value. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. Sierra Pacific 's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of Sierra Pacific 's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of Sierra Pacific 's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of Sierra Pacific 's long-term debt as of December 31 (in millions): 2016 2015 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 1,119 $ 1,191 $ 1,165 $ 1,248

Other, Net (Notes)

Other, Net (Notes)	12 Months Ended
	Dec. 31, 2016
MidAmerican Energy Company [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, Net [Text Block]	Other Income and (Expense) - Other, Net Other, net, as shown on the Statements of Operations, includes the following other income (expense) items for the years ended December 31 (in millions): 2016 2015 2014 Corporate-owned life insurance income $ 8 $ 4 $ 8 Gain on redemption of auction rate securities 5 — — Other, net 1 1 2 Total $ 14 $ 5 $ 10
MidAmerican Funding, LLC and Subsidiaries [Domain]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, Net [Text Block]	Other Income and (Expense) - Other, Net Other, net, as shown on the Consolidated Statements of Operations, includes the following other income (expense) items for the years ended December 31 (in millions): 2016 2015 2014 Corporate-owned life insurance income $ 8 $ 4 $ 8 Gain on redemption of auction rate securities 5 — — Gains on sales of assets and other investments 3 13 — Leveraged leases — 1 5 Other, net 3 1 5 Total $ 19 $ 19 $ 18 MidAmerican Funding recognized a $13 million pre-tax gain on the sale of an investment in a generating facility lease in 2015.

Income Taxes (Notes)

Income Taxes (Notes)	12 Months Ended
	Dec. 31, 2016
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Income Taxes [Text Block]	Income Taxes Income tax expense (benefit) consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Current: Federal $ (743 ) $ (929 ) $ (1,872 ) State 1 29 (3 ) Foreign 55 84 129 (687 ) (816 ) (1,746 ) Deferred: Federal 1,164 1,310 2,296 State (59 ) (53 ) 37 Foreign (7 ) 17 11 1,098 1,274 2,344 Investment tax credits (8 ) (8 ) (9 ) Total $ 403 $ 450 $ 589 A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income before income tax expense is as follows for the years ended December 31: 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (14 ) (11 ) (10 ) State income tax, net of federal income tax benefit (1 ) (1 ) 1 Income tax effect of foreign income (6 ) (7 ) (3 ) Equity income 2 2 2 Other, net (2 ) (2 ) (2 ) Effective income tax rate 14 % 16 % 23 % Income tax credits relate primarily to production tax credits from wind-powered generating facilities owned by MidAmerican Energy, PacifiCorp and BHE Renewables. Federal renewable electricity production tax credits are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in-service. Income tax effect of foreign income includes, among other items, deferred income tax benefits of $16 million in 2016 and $39 million in 2015 related to the enactment of reductions in the United Kingdom corporate income tax rate. In September 2016, the corporate income tax rate was reduced from 18% to 17% effective April 1, 2020. In November 2015, the corporate income tax rate was reduced from 20% to 19% effective April 1, 2017, with a further reduction to 18% effective April 1, 2020. Berkshire Hathaway includes the Company in its United States federal income tax return. As of December 31, 2016 , the Company had current income taxes payable to Berkshire Hathaway of $27 million . As of December 31, 2015 , the Company had current income taxes receivable from Berkshire Hathaway of $286 million . The net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Federal, state and foreign carryforwards $ 987 $ 865 Regulatory liabilities 909 834 AROs 326 317 Employee benefits 209 190 Derivative contracts 29 83 Other 707 815 Total deferred income tax assets 3,167 3,104 Valuation allowances (64 ) (35 ) Total deferred income tax assets, net 3,103 3,069 Deferred income tax liabilities: Property-related items (14,237 ) (13,157 ) Regulatory assets (1,449 ) (1,446 ) Investments (962 ) (852 ) Other (334 ) (299 ) Total deferred income tax liabilities (16,982 ) (15,754 ) Net deferred income tax liability $ (13,879 ) $ (12,685 ) The following table provides the Company's net operating loss and tax credit carryforwards and expiration dates as of December 31, 2016 (in millions): Federal State Foreign Total Net operating loss carryforwards (1) $ 179 $ 11,549 $ 352 $ 12,080 Deferred income taxes on net operating loss carryforwards $ 65 $ 674 $ 95 $ 834 Expiration dates 2023-2025 2017-2036 2035-2036 Tax credits (2) $ 128 $ 25 $ — $ 153 Expiration dates 2023- indefinite 2017- indefinite (1) The federal net operating loss carry forwards relate principally to net operating loss carry forwards of subsidiaries that are tax residents in both the United States and the United Kingdom. The federal net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2023. (2) Includes $97 million of deferred foreign tax credits associated with the federal income tax on unremitted tax earnings and profit pools that will begin to be creditable and expire 10 years after the date the foreign earnings are repatriated through actual or deemed dividends. As of December 31, 2016 the statute of limitation had not begun on the foreign tax credit carryforwards. The United States Internal Revenue Service has closed its examination of the Company's income tax returns through December 31, 2009. Most state tax agencies have closed their examinations of the Company's income tax returns through February 9, 2006, except for (i) Iowa, which is closed through December 31, 2012, (ii) Illinois, which is closed through December 31, 2008 and (iii) the statute of limitations for PacifiCorp's state income tax returns have expired through December 31, 2009, with the exception of California, Oregon and Utah, for which the statute of limitations have expired through March 31, 2006. Examinations have been closed in the United Kingdom through December 31, 2014, in Canada through December 31, 2008 and in the Philippines through December 31, 2012. A reconciliation of the beginning and ending balances of the Company's net unrecognized tax benefits is as follows for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 198 $ 220 Additions based on tax positions related to the current year 7 3 Additions for tax positions of prior years 6 46 Reductions for tax positions of prior years (11 ) (58 ) Statute of limitations (1 ) (6 ) Settlements (67 ) (6 ) Interest and penalties (4 ) (1 ) Ending balance $ 128 $ 198 As of December 31, 2016 and 2015 , the Company had unrecognized tax benefits totaling $104 million and $163 million , respectively, that if recognized, would have an impact on the effective tax rate. The remaining unrecognized tax benefits relate to tax positions for which ultimate deductibility is highly certain but for which there is uncertainty as to the timing of such deductibility. Recognition of these tax benefits, other than applicable interest and penalties, would not affect the Company's effective income tax rate.
PacifiCorp [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Income Taxes [Text Block]	Income Taxes Income tax expense (benefit) consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Current: Federal $ 169 $ 130 $ 2 State 32 26 10 Total 201 156 12 Deferred: Federal 123 148 260 State 21 29 43 Total 144 177 303 Investment tax credits (5 ) (5 ) (6 ) Total income tax expense $ 340 $ 328 $ 309 A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income before income tax expense is as follows for the years ended December 31: 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % State income taxes, net of federal income tax benefit 3 3 3 Federal income tax credits (6 ) (6 ) (7 ) Other (1 ) — — Effective income tax rate 31 % 32 % 31 % Income tax credits relate primarily to production tax credits earned by PacifiCorp's wind-powered generating facilities. Federal renewable electricity production tax credits are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in-service. The net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Regulatory liabilities $ 393 $ 374 Employee benefits 202 189 Derivative contracts and unamortized contract values 67 94 State carryforwards 69 68 Loss contingencies 12 67 Asset retirement obligations 78 81 Other 82 88 903 961 Deferred income tax liabilities: Property, plant and equipment (5,161 ) (5,030 ) Regulatory assets (586 ) (639 ) Other (36 ) (42 ) (5,783 ) (5,711 ) Net deferred income tax liability $ (4,880 ) $ (4,750 ) The following table provides PacifiCorp's net operating loss and tax credit carryforwards and expiration dates as of December 31, 2016 (in millions): State Net operating loss carryforwards $ 1,415 Deferred income taxes on net operating loss carryforwards $ 52 Expiration dates 2017 - 2032 Tax credit carryforwards $ 17 Expiration dates 2017 - indefinite The United States Internal Revenue Service has closed its examination of PacifiCorp's income tax returns through December 31, 2009. The statute of limitations for PacifiCorp's state income tax returns have expired through December 31, 2009, with the exception of California, Oregon and Utah, for which the statute of limitations have expired through March 31, 2006. As of December 31, 2016 and 2015 , PacifiCorp had unrecognized tax benefits totaling $12 million and $13 million , respectively, related to tax positions for which ultimate deductibility is highly certain but for which there is uncertainty as to the timing of such deductibility. Recognition of these tax benefits, other than applicable interest and penalties, would not affect PacifiCorp's effective income tax rate.
MidAmerican Energy Company [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Income Taxes [Text Block]	Income Taxes MidAmerican Energy's income tax benefit from continuing operations consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Current: Federal $ (479 ) $ (415 ) $ (411 ) State (14 ) (6 ) (4 ) (493 ) (421 ) (415 ) Deferred: Federal 366 281 298 State (4 ) (6 ) 2 362 275 300 Investment tax credits (1 ) (1 ) (1 ) Total $ (132 ) $ (147 ) $ (116 ) A reconciliation of the federal statutory income tax rate to MidAmerican Energy's effective income tax rate applicable to income before income tax benefit from continuing operations is as follows for the years ended December 31: 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (61 ) (71 ) (65 ) State income tax, net of federal income tax benefit (3 ) (2 ) — Effects of ratemaking (3 ) (12 ) (9 ) Other, net — 1 (2 ) Effective income tax rate (32 )% (49 )% (41 )% Income tax credits relate primarily to production tax credits earned by MidAmerican Energy's wind-powered generating facilities. Federal renewable electricity production tax credits are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in service. MidAmerican Energy's net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Regulatory liabilities $ 333 $ 327 Asset retirement obligations 230 214 Employee benefits 66 66 Other 74 88 Total deferred income tax assets 703 695 Deferred income tax liabilities: Depreciable property (3,763 ) (3,321 ) Regulatory assets (471 ) (418 ) Other (41 ) (17 ) Total deferred income tax liabilities (4,275 ) (3,756 ) Net deferred income tax liability $ (3,572 ) $ (3,061 ) As of December 31, 2016 , MidAmerican Energy has available $25 million of state tax carryforwards, principally related to $549 million of net operating losses, that expire at various intervals between 2017 and 2035 . The United States Internal Revenue Service has closed its examination of BHE's income tax returns through December 31, 2009, including components related to MidAmerican Energy. In addition, state jurisdictions have closed their examinations of MidAmerican Energy's income tax returns for Iowa through December 31, 2012, for Illinois through December 31, 2008, and for other jurisdictions through December 31, 2009. A reconciliation of the beginning and ending balances of MidAmerican Energy's net unrecognized tax benefits is as follows for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 10 $ 26 Additions based on tax positions related to the current year — 3 Additions for tax positions of prior years 10 47 Reductions based on tax positions related to the current year (2 ) (6 ) Reductions for tax positions of prior years (8 ) (46 ) Statute of limitations — (5 ) Settlements — (6 ) Interest and penalties — (3 ) Ending balance $ 10 $ 10 As of December 31, 2016 , MidAmerican Energy had unrecognized tax benefits totaling $29 million that, if recognized, would have an impact on the effective tax rate. The remaining unrecognized tax benefits relate to tax positions for which ultimate deductibility is highly certain but for which there is uncertainty as to the timing of such deductibility. Recognition of these tax benefits, other than applicable interest and penalties, would not affect MidAmerican Energy's effective income tax rate.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Income Taxes [Text Block]	Income Taxes MidAmerican Funding's income tax benefit from continuing operations consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Current: Federal $ (485 ) $ (418 ) $ (414 ) State (16 ) (8 ) (5 ) (501 ) (426 ) (419 ) Deferred: Federal 367 282 296 State (4 ) (5 ) 2 363 277 298 Investment tax credits (1 ) (1 ) (1 ) Total $ (139 ) $ (150 ) $ (122 ) A reconciliation of the federal statutory income tax rate MidAmerican Funding's the effective income tax rate applicable to income before income tax benefit from continuing operations is as follows for the years ended December 31: 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (64 ) (72 ) (68 ) State income tax, net of federal income tax benefit (3 ) (3 ) (1 ) Effects of ratemaking (3 ) (12 ) (10 ) Other, net — 1 (1 ) Effective income tax rate (35 )% (51 )% (45 )% Income tax credits relate primarily to production tax credits earned by MidAmerican Energy's wind-powered generating facilities. Federal renewable electricity production tax credits are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in service. MidAmerican Funding's net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Regulatory liabilities $ 333 $ 327 Employee benefits 66 66 Asset retirement obligations 230 214 Other 82 97 Total deferred income tax assets 711 704 Deferred income tax liabilities: Depreciable property (3,767 ) (3,326 ) Regulatory assets (471 ) (418 ) Other (41 ) (16 ) Total deferred income tax liabilities (4,279 ) (3,760 ) Net deferred income tax liability $ (3,568 ) $ (3,056 ) As of December 31, 2016 , MidAmerican Funding has available $25 million of state tax carryforwards, principally related to $549 million of net operating losses, that expire at various intervals between 2017 and 2035 . The United States Internal Revenue Service has closed its examination of BHE's income tax returns through December 31, 2009, including components related to MidAmerican Funding. In addition, state jurisdictions have closed their examinations of MidAmerican Funding's income tax returns for Iowa through December 31, 2012, for Illinois through December 31, 2008, and for other jurisdictions through December 31, 2009. A reconciliation of the beginning and ending balances of MidAmerican Funding's net unrecognized tax benefits is as follows for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 10 $ 26 Additions based on tax positions related to the current year — 4 Additions for tax positions of prior years 10 46 Reductions based on tax positions related to the current year (2 ) (6 ) Reductions for tax positions of prior years (8 ) (46 ) Statute of limitations — (5 ) Settlements — (6 ) Interest and penalties — (3 ) Ending balance $ 10 $ 10 As of December 31, 2016 , MidAmerican Funding had unrecognized tax benefits totaling $30 million that, if recognized, would have an impact on the effective tax rate. The remaining unrecognized tax benefits relate to tax positions for which ultimate deductibility is highly certain but for which there is uncertainty as to the timing of such deductibility. Recognition of these tax benefits, other than applicable interest and penalties, would not affect MidAmerican Funding's effective income tax rate.
Nevada Power Company [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Income Taxes [Text Block]	Income Taxes Income tax expense (benefit) consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Current – Federal $ 68 $ — $ — Deferred – Federal 79 163 131 Investment tax credits (1 ) (1 ) (1 ) Total income tax expense $ 146 $ 162 $ 130 A reconciliation of the federal statutory income rate to the effective income tax rate applicable to income before income tax expense is as follows for the years ended December 31 : 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % Effects of ratemaking — 1 1 Other (1 ) — — Effective income tax rate 34 % 36 % 36 % The net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Capital and financial leases 170 174 Regulatory liabilities 83 47 Employee benefits 29 30 Customer advances 23 22 Federal net operating loss and credit carryforwards 5 15 Other 16 17 Total deferred income tax assets 326 305 Valuation allowance (5 ) (5 ) Total deferred income tax assets, net 321 300 Deferred income tax liabilities: Property related items (1,293 ) (1,242 ) Regulatory assets (321 ) (275 ) Capital and financial leases (165 ) (169 ) Other (16 ) (19 ) Total deferred income tax liabilities (1,795 ) (1,705 ) Net deferred income tax liability $ (1,474 ) $ (1,405 ) The following table provides Nevada Power 's tax credit carryforwards and expiration dates as of December 31 , 2016 (in millions): Other tax credits $ 5 Expiration dates 2017 - 2028 The United States federal jurisdiction is the only significant income tax jurisdiction for NV Energy . In July 2012, the United States Internal Revenue Service and the Joint Committee on Taxation concluded their examination of NV Energy with respect to its United States federal income tax returns for December 31, 2005 through December 31, 2008.
Sierra Pacific Power Company [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Income Taxes [Text Block]	Income Taxes Income tax expense (benefit) consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Deferred - Federal $ 50 $ 48 $ 48 Investment tax credits (1 ) (1 ) (1 ) Total income tax expense $ 49 $ 47 $ 47 A reconciliation of the federal statutory income rate to the effective income tax rate applicable to income before income tax expense is as follows for the years ended December 31 : 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % Effects of ratemaking 1 1 1 Other 1 — (1 ) Effective income tax rate 37 % 36 % 35 % The net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Federal net operating loss and credit carryforwards $ 25 $ 39 Employee benefit plans 22 25 Regulatory liabilities 16 19 Capital and financial lease liabilities 12 13 Customer Advances 9 8 Commodity derivative contract 5 5 Other 6 7 Total deferred income tax assets $ 95 $ 116 Deferred income tax liabilities: Property related items $ (562 ) $ (538 ) Regulatory assets (124 ) (121 ) Capital and financial leases (12 ) (13 ) Other (14 ) (14 ) Total deferred income tax liabilities $ (712 ) $ (686 ) Net deferred income tax liability $ (617 ) $ (570 ) The following table provides Sierra Pacific 's federal net operating loss and tax credit carryforwards and expiration dates as of December 31 , 2016 (in millions): Net operating loss carryforwards $ 55 Deferred income taxes on federal net operating loss carryforwards $ 19 Expiration dates 2031 - 2033 Other tax credits $ 6 Expiration dates 2021 - 2032 The United States federal jurisdiction is the only significant income tax jurisdiction for NV Energy . In July 2012, the United States Internal Revenue Service and the Joint Committee on Taxation concluded their examination of NV Energy with respect to its United States federal income tax returns for December 31, 2005 through December 31, 2008.

Supplemental Cash Flow Disclosu

Supplemental Cash Flow Disclosures Supplemental Cash Flow Disclosures (Notes)	12 Months Ended
	Dec. 31, 2016
Condensed Cash Flow Statements, Captions [Line Items]
Supplemental Cash Flow Disclosures [Text Block]	Supplemental Cash Flow Disclosures The summary of supplemental cash flow disclosures as of and for the years ending December 31 is as follows (in millions): 2016 2015 2014 Supplemental disclosure of cash flow information: Interest paid, net of amounts capitalized $ 1,673 $ 1,764 $ 1,585 Income taxes received, net (1) $ 1,016 $ 1,666 $ 635 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 547 $ 718 $ 1,143 (1) Includes $1.1 billion , $1.8 billion and $764 million of income taxes received from Berkshire Hathaway in 2016 , 2015 and 2014 , respectively.
PacifiCorp [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Supplemental Cash Flow Disclosures [Text Block]	Supplemental Cash Flow Disclosures The summary of supplemental cash flow disclosures as of and for the years ended December 31 is as follows (in millions): 2016 2015 2014 Interest paid, net of amounts capitalized $ 350 $ 342 $ 340 Income taxes paid, net $ 201 $ 40 $ 161 Supplemental disclosure of non-cash investing and financing activities: Accounts payable related to property, plant and equipment additions $ 101 $ 147 $ 140 Accounts receivable related to property, plant and equipment sales $ — $ 40 $ —
MidAmerican Energy Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Supplemental Cash Flow Disclosures [Text Block]	Supplemental Cash Flow Disclosures The summary of supplemental cash flow disclosures as of and for the years ending December 31 is as follows (in millions): 2016 2015 2014 Supplemental cash flow information: Interest paid, net of amounts capitalized $ 181 $ 154 $ 144 Income taxes received, net $ 601 $ 629 $ 149 Supplemental disclosure of non-cash investing transactions: Accounts payable related to utility plant additions $ 131 $ 249 $ 128 Dividend of unregulated retail services business (Note 3) $ 90 $ — $ —
MidAmerican Funding, LLC and Subsidiaries [Domain]
Condensed Cash Flow Statements, Captions [Line Items]
Supplemental Cash Flow Disclosures [Text Block]	Supplemental Cash Flow Information The summary of supplemental cash flow information as of and for the years ending December 31 is as follows (in millions): 2016 2015 2014 Supplemental cash flow information: Interest paid, net of amounts capitalized $ 204 $ 177 $ 167 Income taxes received, net $ 609 $ 630 $ 153 Supplemental disclosure of non-cash investing transactions: Accounts payable related to utility plant additions $ 131 $ 249 $ 128 Transfer of assets and liabilities to affiliate (Note 3) $ 90 $ — $ —
Nevada Power Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Supplemental Cash Flow Disclosures [Text Block]	Supplemental Cash Flow Disclosures The summary of supplemental cash flow disclosures as of and for the years ended December 31 is as follows (in millions): 2016 2015 2014 Supplemental disclosure of cash flow information - Interest paid, net of amounts capitalized $ 173 $ 186 $ 194 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 19 $ 51 $ 30 Capital and financial lease obligations incurred $ (1 ) $ (5 ) $ 7
Sierra Pacific Power Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Supplemental Cash Flow Disclosures [Text Block]	Supplemental Cash Flow Disclosures The summary of supplemental cash flow disclosures as of and for the years ended December 31 is as follows (in millions): 2016 2015 2014 Supplemental disclosure of cash flow information - Interest paid, net of amounts capitalized $ 47 $ 54 $ 54 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 15 $ 24 $ 31 Capital and financial lease obligations incurred $ — $ 13 $ 1

Related Party Transactions Rela

Related Party Transactions Related Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2016
PacifiCorp [Member]
Related Party Transaction [Line Items]
Related Party Transactions Disclosure [Text Block]	PacifiCorp has an intercompany administrative services agreement with BHE and its subsidiaries. Amounts charged to PacifiCorp by BHE and its subsidiaries under this agreement totaled $10 million during each of the years ended December 31, 2016 , 2015 2014 , respectively. Payables associated with these administrative services were $2 million as of December 31, 2016 and 2015 , respectively. Amounts charged by PacifiCorp to BHE and its subsidiaries under this agreement totaled $4 million , $7 million and $10 million during the years ended December 31, 2016 , 2015 and 2014 , respectively. Receivables associated with these administrative services were $1 million as of December 31, 2016 and 2015 , respectively. PacifiCorp also engages in various transactions with several subsidiaries of BHE in the ordinary course of business. Services provided by these subsidiaries in the ordinary course of business and charged to PacifiCorp primarily relate to wholesale electricity purchases and transmission of electricity, transportation of natural gas and employee relocation services. These expenses totaled $7 million , $8 million and $7 million during the years ended December 31, 2016 , 2015 and 2014 , respectively. Payables associated with these services were $1 million as of December 31, 2016 and 2015 , respectively. Amounts charged by PacifiCorp to subsidiaries of BHE for wholesale electricity sales in the ordinary course of business totaled $1 million , $2 million and $5 million during the years ended December 31, 2016 , 2015 and 2014 , respectively. PacifiCorp has long-term transportation contracts with BNSF Railway Company ("BNSF"), an indirect wholly owned subsidiary of Berkshire Hathaway, PacifiCorp's ultimate parent company. Transportation costs under these contracts were $37 million during the year ended December 31, 2016 and $39 million during the years ended December 31, 2015 and 2014 . As of December 31, 2016 and 2015 , PacifiCorp had $1 million , respectively, of accounts payable to BNSF outstanding under these contracts, including indirect payables related to a jointly owned facility. PacifiCorp participated in a captive insurance program provided by MEHC Insurance Services Ltd. ("MEISL"), a wholly owned subsidiary of BHE. MEISL covered all or significant portions of the property damage and liability insurance deductibles in many of PacifiCorp's policies, as well as overhead distribution and transmission line property damage. The policy coverage period expired on March 20, 2011 and was not renewed. Proceeds from claims were $- million, $2 million and $- million during the years ended December 31, 2016 , 2015 and 2014 , respectively. PacifiCorp is party to a tax-sharing agreement and is part of the Berkshire Hathaway United States federal income tax return. Federal and state income taxes receivable from BHE were $17 million as of December 31, 2016 and 2015, respectively. For the years ended December 31, 2016 , 2015 and 2014 , cash paid for federal and state income taxes to BHE totaled $201 million , $40 million and $161 million , respectively. PacifiCorp transacts with its equity investees, Bridger Coal and Trapper Mining Inc. During the years ended December 31, 2016 , 2015 and 2014 , PacifiCorp charged Bridger Coal $2 million , $19 million and $3 million , respectively, primarily for the sale of mining equipment in 2015, administrative support and management services, as well as materials, provided by PacifiCorp to Bridger Coal. Receivables for these services, as well as for certain expenses paid by PacifiCorp and reimbursed by Bridger Coal, were $5 million and $4 million as of December 31, 2016 and 2015 , respectively. Services provided by equity investees to PacifiCorp primarily relate to coal purchases. During the years ended December 31, 2016 , 2015 and 2014 , coal purchases from PacifiCorp's equity investees totaled $174 million , $181 million and $146 million , respectively. Payables to PacifiCorp's equity investees were $17 million and $16 million as of December 31, 2016 and 2015 , respectively.
MidAmerican Energy Company [Member]
Related Party Transaction [Line Items]
Related Party Transactions Disclosure [Text Block]	Related Party Transactions The companies identified as affiliates of MidAmerican Energy are Berkshire Hathaway and its subsidiaries, including BHE and its subsidiaries. The basis for the following transactions is provided for in service agreements between MidAmerican Energy and the affiliates. MidAmerican Energy is reimbursed for charges incurred on behalf of its affiliates. The majority of these reimbursed expenses are for general costs, such as insurance and building rent, and for employee wages, benefits and costs related to corporate functions such as information technology, human resources, treasury, legal and accounting. The amount of such reimbursements was $41 million , $46 million and $58 million for 2016 , 2015 and 2014 , respectively. MidAmerican Energy reimbursed BHE in the amount of $6 million , $7 million and $8 million in 2016 , 2015 and 2014 , respectively, for its share of corporate expenses. MidAmerican Energy purchases natural gas transportation and storage capacity services from Northern Natural Gas Company, a wholly owned subsidiary of BHE, and coal transportation services from BNSF Railway Company, a wholly-owned subsidiary of Berkshire Hathaway, in the normal course of business at either tariffed or market prices. These purchases totaled $135 million , $165 million and $144 million in 2016 , 2015 and 2014 , respectively. MidAmerican Energy had accounts receivable from affiliates of $5 million as of December 31, 2016 and 2015 , that are included in receivables on the Balance Sheets. MidAmerican Energy also had accounts payable to affiliates of $13 million as of December 31, 2016 and 2015 , that are included in accounts payable on the Balance Sheets. MidAmerican Energy is party to a tax-sharing agreement and is part of the Berkshire Hathaway United States federal income tax return. For current federal and state income taxes, MidAmerican Energy had a payable to BHE of $6 million as of December 31, 2016, and a receivable from BHE of $102 million as of December 31, 2015. MidAmerican Energy received net cash receipts for federal and state income taxes from BHE totaling $601 million , $629 million and $149 million for the years ended December 31, 2016 , 2015 and 2014 , respectively. MidAmerican Energy recognizes the full amount of the funded status for its pension and postretirement plans, and amounts attributable to MidAmerican Energy's affiliates that have not previously been recognized through income are recognized as an intercompany balance with such affiliates. MidAmerican Energy adjusts these balances when changes to the funded status of the respective plans are recognized and does not intend to settle the balances currently. Amounts receivable from affiliates attributable to the funded status of employee benefit plans totaled $12 million and $10 million as of December 31, 2016 and 2015 , respectively, and similar amounts payable to affiliates totaled $36 million and $29 million as of December 31, 2016 and 2015 , respectively. See Note 11 for further information pertaining to pension and postretirement accounting.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Related Party Transaction [Line Items]
Related Party Transactions Disclosure [Text Block]	Related Party Transactions The companies identified as affiliates of MidAmerican Funding are Berkshire Hathaway and its subsidiaries, including BHE and its subsidiaries. The basis for the following transactions is provided for in service agreements between MidAmerican Funding and the affiliates. MidAmerican Funding is reimbursed for charges incurred on behalf of its affiliates. The majority of these reimbursed expenses are for allocated general costs, such as insurance and building rent, and for employee wages, benefits and costs for corporate functions, such as information technology, human resources, treasury, legal and accounting. The amount of such reimbursements was $35 million , $35 million and $37 million for 2016 , 2015 and 2014 , respectively. MidAmerican Funding reimbursed BHE in the amount of $6 million , $7 million and $8 million in 2016 , 2015 and 2014 , respectively, for its share of corporate expenses. MidAmerican Energy purchases natural gas transportation and storage capacity services from Northern Natural Gas Company, a wholly owned subsidiary of BHE, and coal transportation services from BNSF Railway Company, a wholly-owned subsidiary of Berkshire Hathaway, in the normal course of business at either tariffed or market prices. These purchases totaled $135 million , $165 million and $144 million in 2016 , 2015 and 2014 , respectively. MHC has a $300 million revolving credit arrangement carrying interest at the 30-day LIBOR rate plus a spread to borrow from BHE. Outstanding balances are unsecured and due on demand. The outstanding balance was $31 million at an interest rate of 0.885% as of December 31, 2016 , and $139 million at an interest rate of 0.494% as of December 31, 2015 , and is reflected as note payable to affiliate on the Consolidated Balance Sheet. BHE has a $100 million revolving credit arrangement, carrying interest at the 30-day LIBOR rate plus a spread to borrow from MHC. Outstanding balances are unsecured and due on demand. There were no borrowings outstanding throughout 2016 and 2015 . MidAmerican Funding had accounts receivable from affiliates of $7 million as of December 31, 2016 and 2015 that are included in receivables, net on the Consolidated Balance Sheets. MidAmerican Funding also had accounts payable to affiliates of $12 million as of December 31, 2016 and 2015 , that are included in accounts payable on the Consolidated Balance Sheets. MidAmerican Funding is party to a tax-sharing agreement and is part of the Berkshire Hathaway United States federal income tax return. For current federal and state income taxes, MidAmerican Funding had a payable to BHE of $7 million as of December 31, 2016, and a receivable from BHE of $102 million as of December 31, 2015. MidAmerican Funding received net cash receipts for federal and state income taxes from BHE totaling $609 million , $631 million and $154 million for the years ended December 31, 2016 , 2015 and 2014 , respectively. MidAmerican Funding recognizes the full amount of the funded status for its pension and postretirement plans, and amounts attributable to MidAmerican Funding's affiliates that have not previously been recognized through income are recognized as an intercompany balance with such affiliates. MidAmerican Funding adjusts these balances when changes to the funded status of the respective plans are recognized and does not intend to settle the balances currently. Amounts receivable from affiliates attributable to the funded status of employee benefit plans totaled $12 million and $10 million as of December 31, 2016 and 2015 , respectively, and similar amounts payable to affiliates totaled $36 million and $29 million as of December 31, 2016 and 2015 , respectively. See Note 11 for further information pertaining to pension and postretirement accounting. The indenture pertaining to MidAmerican Funding's long-term debt restricts MidAmerican Funding from paying a distribution on its equity securities, unless after making such distribution either its debt to total capital ratio does not exceed 0.67:1 and its interest coverage ratio is not less than 2.2:1 or its senior secured long-term debt rating is at least BBB or its equivalent. MidAmerican Funding may seek a release from this restriction upon delivery to the indenture trustee of written confirmation from the ratings agencies that without this restriction MidAmerican Funding's senior secured long-term debt would be rated at least BBB+.
Nevada Power Company [Member]
Related Party Transaction [Line Items]
Related Party Transactions Disclosure [Text Block]	Related Party Transactions Kern River Gas Transmission Company, an indirect subsidiary of BHE , provided natural gas transportation and other services to Nevada Power of $68 million for each of the years ended December 31 , 2016 , 2015 and 2014 . As of December 31 , 2016 and 2015 , Nevada Power 's Consolidated Balance Sheets included amounts due to Kern River Gas Transmission Company of $5 million . Nevada Power provided electricity and other services to PacifiCorp , an indirect subsidiary of BHE , of $2 million , $3 million and $3 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. There were no receivables associated with these services as of December 31 , 2016 and 2015 . PacifiCorp provided electricity and the sale of renewable energy credits to Nevada Power of $- million, $2 million and $5 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. There were no payables associated with these transactions as of December 31 , 2016 and 2015 . Nevada Power provided electricity to Sierra Pacific of $78 million , $69 million and $33 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. Receivables associated with these transactions were $45 million and $15 million as of December 31 , 2016 and 2015 , respectively. Nevada Power purchased electricity from Sierra Pacific of $17 million , $2 million and $8 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. Payables associated with these transactions were $12 million and $1 million as of December 31 , 2016 and 2015 , respectively. Nevada Power incurs intercompany administrative and shared facility costs with NV Energy and Sierra Pacific . These transactions are governed by an intercompany service agreement and are priced at cost. Nevada Power provided services to NV Energy of $1 million for each of the years ending December 31 , 2016 , 2015 and 2014 . NV Energy provided services to Nevada Power of $10 million , $12 million and $19 million for the years ending December 31 , 2016 , 2015 and 2014 , respectively. Nevada Power provided services to Sierra Pacific of $24 million , $22 million and $20 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. Sierra Pacific provided services to Nevada Power of $14 million , $16 million and $16 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. As of December 31 , 2016 and 2015 , Nevada Power 's Consolidated Balance Sheets included amounts due to NV Energy of $32 million and $40 million , respectively. There were no receivables due from NV Energy as of December 31 , 2016 and 2015 . As of December 31 , 2016 and 2015 , Nevada Power 's Consolidated Balance Sheets included receivables due from Sierra Pacific of $4 million and $6 million , respectively. There were no payables due to Sierra Pacific as of December 31 , 2016 and 2015 . Nevada Power is party to a tax-sharing agreement with NV Energy and NV Energy is part of the Berkshire Hathaway United States federal income tax return. Federal income taxes payable to NV Energy were $68 million and $- million as of December 31, 2016 and 2015, respectively. No cash payments were made for federal income taxes for the years ended December 31 , 2016 , 2015 and 2014 . Certain disbursements for accounts payable and payroll are made by NV Energy on behalf of Nevada Power and reimbursed automatically when settled by the bank. These amounts are recorded as accounts payable at the time of disbursement.
Sierra Pacific Power Company [Member]
Related Party Transaction [Line Items]
Related Party Transactions Disclosure [Text Block]	Related Party Transactions Sierra Pacific provided electricity to Nevada Power of $17 million , $2 million and $8 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. Receivables associated with these transactions were $12 million and $1 million as of December 31 , 2016 and 2015 . Sierra Pacific purchased electricity from Nevada Power of $78 million , $69 million and $33 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. Payables associated with these transactions were $45 million and $15 million as of December 31 , 2016 and 2015 , respectively. Sierra Pacific incurs intercompany administrative and shared facility costs with NV Energy and Nevada Power . These transactions are governed by an intercompany service agreement and are priced at cost. NV Energy provided services to Sierra Pacific of $5 million , $6 million and $9 million for the years ending December 31 , 2016 , 2015 and 2014 , respectively. Sierra Pacific provided services to Nevada Power of $14 million , $16 million , and $16 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. Nevada Power provided services to Sierra Pacific of $24 million , $22 million , and $20 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. As of December 31 , 2016 and 2015 , Sierra Pacific 's Consolidated Balance Sheets included amounts due to NV Energy of $18 million and $21 million , respectively. There were no receivables due from NV Energy as of December 31 , 2016 and 2015 . As of December 31 , 2016 and 2015 , Sierra Pacific 's Consolidated Balance Sheets included payables due to Nevada Power of $4 million and $6 million , respectively. There were no receivables due from Nevada Power as of December 31 , 2016 and 2015 . Certain disbursements for accounts payable and payroll are made by NV Energy on behalf of Sierra Pacific and reimbursed automatically when settled by the bank. These amounts are recorded as accounts payable at the time of disbursement.

Employee Benefit Plans (Notes)

Employee Benefit Plans (Notes)	12 Months Ended
	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Employee Benefit Plans [Text Block]	Employee Benefit Plans Defined Benefit Plans Domestic Operations The Utilities sponsor defined benefit pension plans that cover a majority of all employees of BHE and its domestic energy subsidiaries. These pension plans include noncontributory defined benefit pension plans, supplemental executive retirement plans ("SERP") and a restoration plan for certain executives of NV Energy. The Utilities also provide certain postretirement healthcare and life insurance benefits through various plans to eligible retirees. Net Periodic Benefit Cost For purposes of calculating the expected return on plan assets, a market-related value is used. The market-related value of plan assets is calculated by spreading the difference between expected and actual investment returns over a five-year period beginning after the first year in which they occur. Net periodic benefit cost for the plans included the following components for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Service cost $ 29 $ 33 $ 36 $ 9 $ 11 $ 14 Interest cost 126 121 131 31 31 46 Expected return on plan assets (160 ) (169 ) (164 ) (41 ) (45 ) (53 ) Net amortization 46 53 44 (12 ) (11 ) (3 ) Net periodic benefit cost (credit) $ 41 $ 38 $ 47 $ (13 ) $ (14 ) $ 4 Funded Status The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, beginning of year $ 2,489 $ 2,718 $ 662 $ 858 Employer contributions 78 13 2 2 Participant contributions — — 10 9 Actual return on plan assets 163 (17 ) 41 — Settlement (11 ) (23 ) — (150 ) Benefits paid (194 ) (202 ) (49 ) (57 ) Plan assets at fair value, end of year $ 2,525 $ 2,489 $ 666 $ 662 The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Benefit obligation, beginning of year $ 2,934 $ 3,119 $ 740 $ 936 Service cost 29 33 9 11 Interest cost 126 121 31 31 Participant contributions — — 10 9 Actuarial loss (gain) 67 (110 ) (7 ) (43 ) Amendment 1 (4 ) — 3 Settlement (11 ) (23 ) — (150 ) Benefits paid (194 ) (202 ) (49 ) (57 ) Benefit obligation, end of year $ 2,952 $ 2,934 $ 734 $ 740 Accumulated benefit obligation, end of year $ 2,929 $ 2,906 In December 2014, PacifiCorp's subsidiary, Energy West Mining Company, reached a labor settlement with the UMWA covering union employees at PacifiCorp's Deer Creek mining operations. As a result of the labor settlement, the UMWA agreed to assume PacifiCorp's other postretirement benefit obligation associated with UMWA plan participants in exchange for PacifiCorp transferring $150 million to a fund managed by the UMWA. Transfer of the assets and settlement of this obligation occurred in May 2015 and resulted in a remeasurement of the other postretirement plan assets and benefit obligation. As a result of the remeasurement, PacifiCorp recognized a $9 million settlement loss, with the portion that is probable of recovery deferred as a regulatory asset. No curtailment accounting was triggered as a result of the settlement due to an insignificant impact to the average remaining service lives in the plan. The funded status of the plans and the amounts recognized on the Consolidated Balance Sheets as of December 31 are as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, end of year $ 2,525 $ 2,489 $ 666 $ 662 Benefit obligation, end of year 2,952 2,934 734 740 Funded status $ (427 ) $ (445 ) $ (68 ) $ (78 ) Amounts recognized on the Consolidated Balance Sheets: Other assets $ 26 $ 7 $ 19 $ 15 Other current liabilities (15 ) (15 ) — — Other long-term liabilities (438 ) (437 ) (87 ) (93 ) Amounts recognized $ (427 ) $ (445 ) $ (68 ) $ (78 ) The SERPs and restoration plan have no plan assets; however, the Company has Rabbi trusts that hold corporate-owned life insurance and other investments to provide funding for the future cash requirements of the SERPs and restoration plan. The cash surrender value of all of the policies included in the Rabbi trusts, net of amounts borrowed against the cash surrender value, plus the fair market value of other Rabbi trust investments, was $242 million and $228 million as of December 31, 2016 and 2015 , respectively. These assets are not included in the plan assets in the above table, but are reflected in noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of plan assets, projected benefit obligation and accumulated benefit obligation for (1) pension and other postretirement benefit plans with a projected benefit obligation in excess of the fair value of plan assets and (2) pension plans with an accumulated benefit obligation in excess of the fair value of plan assets as of December 31 are as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Fair value of plan assets $ 1,841 $ 1,811 $ 413 $ 413 Projected benefit obligation $ 2,294 $ 2,263 $ 500 $ 505 Accumulated benefit obligation $ 2,278 $ 2,244 Unrecognized Amounts The portion of the funded status of the plans not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Net loss $ 775 $ 768 $ 88 $ 97 Prior service credit (7 ) (25 ) (52 ) (68 ) Regulatory deferrals (7 ) (2 ) 7 8 Total $ 761 $ 741 $ 43 $ 37 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2016 and 2015 is as follows (in millions): Accumulated Other Regulatory Regulatory Comprehensive Asset Liability Loss Total Pension Balance, December 31, 2014 $ 710 $ (6 ) $ 19 $ 723 Net loss (gain) arising during the year 76 5 (6 ) 75 Net prior service credit arising during the year (4 ) — — (4 ) Net amortization (53 ) — — (53 ) Total 19 5 (6 ) 18 Balance, December 31, 2015 729 (1 ) 13 741 Net loss arising during the year 76 (11 ) — 65 Net prior service cost arising during the year 1 — — 1 Net amortization (45 ) (1 ) — (46 ) Total 32 (12 ) — 20 Balance, December 31, 2016 $ 761 $ (13 ) $ 13 $ 761 Regulatory Regulatory Asset Liability Total Other Postretirement Balance, December 31, 2014 $ 37 $ (14 ) $ 23 Net (gain) loss arising during the year (1 ) 1 — Net prior service cost arising during the year 3 — 3 Net amortization 10 1 11 Total 12 2 14 Balance, December 31, 2015 49 (12 ) 37 Net gain arising during the year (5 ) (1 ) (6 ) Net amortization 11 1 12 Total 6 — 6 Balance, December 31, 2016 $ 55 $ (12 ) $ 43 The net loss, prior service credit and regulatory deferrals that will be amortized in 2017 into net periodic benefit cost are estimated to be as follows (in millions): Net Prior Service Regulatory Loss Credit Deferrals Total Pension $ 33 $ (3 ) $ (2 ) $ 28 Other postretirement 2 (16 ) 1 (13 ) Total $ 35 $ (19 ) $ (1 ) $ 15 Plan Assumptions Weighted-average assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Benefit obligations as of December 31: Discount rate 4.06 % 4.43 % 4.00 % 4.01 % 4.33 % 3.88 % Rate of compensation increase 2.75 % 2.75 % 2.75 % N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.43 % 4.00 % 4.81 % 4.33 % 3.93 % 4.82 % Expected return on plan assets 6.78 % 6.88 % 6.86 % 7.03 % 7.00 % 7.34 % Rate of compensation increase 2.75 % 2.75 % 3.00 % N/A N/A N/A In establishing its assumption as to the expected return on plan assets, the Company utilizes the asset allocation and return assumptions for each asset class based on historical performance and forward-looking views of the financial markets. 2016 2015 Assumed healthcare cost trend rates as of December 31: Healthcare cost trend rate assumed for next year 7.40 % 7.70 % Rate that the cost trend rate gradually declines to 5.00 % 5.00 % Year that the rate reaches the rate it is assumed to remain at 2025 2025 A one percentage-point change in assumed healthcare cost trend rates would have the following effects (in millions): One Percentage-Point Increase Decrease Increase (decrease) in: Total service and interest cost for the year ended December 31, 2016 $ 1 $ — Other postretirement benefit obligation as of December 31, 2016 4 (4 ) Contributions and Benefit Payments Employer contributions to the pension and other postretirement benefit plans are expected to be $14 million and $4 million , respectively, during 2017 . Funding to the established pension trusts is based upon the actuarially determined costs of the plans and the requirements of the Internal Revenue Code, the Employee Retirement Income Security Act of 1974 and the Pension Protection Act of 2006, as amended. The Company considers contributing additional amounts from time to time in order to achieve certain funding levels specified under the Pension Protection Act of 2006, as amended. The Company's funding policy for its other postretirement benefit plans is to generally contribute an amount equal to the net periodic benefit cost. The expected benefit payments to participants in the Company's pension and other postretirement benefit plans for 2017 through 2021 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Other Pension Postretirement 2017 $ 219 $ 56 2018 226 57 2019 224 57 2020 221 60 2021 214 57 2022-2026 1,002 259 Plan Assets Investment Policy and Asset Allocations The Company's investment policy for its pension and other postretirement benefit plans is to balance risk and return through a diversified portfolio of debt securities, equity securities and other alternative investments. Maturities for debt securities are managed to targets consistent with prudent risk tolerances. The plans retain outside investment advisors to manage plan investments within the parameters outlined by each plan's Pension and Employee Benefits Plans Administrative Committee. The investment portfolio is managed in line with the investment policy with sufficient liquidity to meet near-term benefit payments. The target allocations (percentage of plan assets) for the Company's pension and other postretirement benefit plan assets are as follows as of December 31, 2016 : Other Pension Postretirement % % PacifiCorp: Debt securities (1) 33-37 33-37 Equity securities (1) 53-57 61-65 Limited partnership interests 8-12 1-3 Other 0-1 0-1 MidAmerican Energy: Debt securities (1) 20-40 25-45 Equity securities (1) 60-80 50-80 Real estate funds 2-8 — Other 0-5 0-5 NV Energy: Debt securities (1) 53-77 40 Equity securities (1) 23-47 60 (1) For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities. Fair Value Measurements The Company adopted ASU No. 2015-07, "Fair Value Measurement (Topic 820) - Disclosures for Investments in Certain Entities that Calculate Net Asset Value per Share (or its Equivalent)" effective January 1, 2016 under a retrospective method. The following table presents the fair value of plan assets, by major category, for the Company's defined benefit pension plans (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 4 $ 54 $ — $ 58 Debt securities: United States government obligations 161 — — 161 International government obligations — 2 — 2 Corporate obligations — 295 — 295 Municipal obligations — 20 — 20 Agency, asset and mortgage-backed obligations — 112 — 112 Equity securities: United States companies 583 — — 583 International companies 117 — — 117 Investment funds (2) 146 — — 146 Total assets in the fair value hierarchy $ 1,011 $ 483 $ — 1,494 Investment funds (2) measured at net asset value 920 Limited partnership interests (3) measured at net asset value 61 Real estate funds measured at net asset value 50 Total assets measured at fair value $ 2,525 As of December 31, 2015: Cash equivalents $ — $ 26 $ — $ 26 Debt securities: United States government obligations 155 — — 155 International government obligations — 4 — 4 Corporate obligations — 335 — 335 Municipal obligations — 25 — 25 Agency, asset and mortgage-backed obligations — 154 — 154 Equity securities: United States companies 586 — — 586 International companies 122 — — 122 Investment funds (2) 144 — — 144 Total assets in the fair value hierarchy $ 1,007 $ 544 $ — 1,551 Investment funds (2) measured at net asset value 823 Limited partnership interests (3) measured at net asset value 65 Real estate funds measured at net asset value 50 Total assets measured at fair value $ 2,489 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 62% and 38% , respectively, for 2016 and 66% and 34% , respectively, for 2015 . Additionally, these funds are invested in United States and international securities of approximately 60% and 40% , respectively, for 2016 and 58% and 42% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. The following table presents the fair value of plan assets, by major category, for the Company's defined benefit other postretirement plans (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 18 $ 2 $ — $ 20 Debt securities: United States government obligations 19 — — 19 Corporate obligations — 29 — 29 Municipal obligations — 39 — 39 Agency, asset and mortgage-backed obligations — 25 — 25 Equity securities: United States companies 217 — — 217 International companies 5 — — 5 Investment funds (2) 152 — — 152 Total assets in the fair value hierarchy $ 411 $ 95 $ — 506 Investment funds (2) measured at net asset value 156 Limited partnership interests (3) measured at net asset value 4 Total assets measured at fair value $ 666 As of December 31, 2015: Cash equivalents $ 12 $ 1 $ — $ 13 Debt securities: United States government obligations 18 — — 18 Corporate obligations — 33 — 33 Municipal obligations — 41 — 41 Agency, asset and mortgage-backed obligations — 28 — 28 Equity securities: United States companies 216 — — 216 International companies 6 — — 6 Investment funds (2) 149 — — 149 Total assets in the fair value hierarchy $ 401 $ 103 $ — 504 Investment funds (2) measured at net asset value 154 Limited partnership interests (3) measured at net asset value 4 Total assets measured at fair value $ 662 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 63% and 37% , respectively, for both 2016 and 2015 . Additionally, these funds are invested in United States and international securities of approximately 72% and 28% , respectively, for 2016 and 70% and 30% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. For level 1 investments, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. For level 2 investments, the fair value is determined using pricing models based on observable market inputs. Shares of mutual funds not registered under the Securities Act of 1933, private equity limited partnership interests, common and commingled trust funds and investment entities are reported at fair value based on the net asset value per unit, which is used for expedience purposes. A fund’s net asset value is based on the fair value of the underlying assets held by the fund less its liabilities. Foreign Operations Certain wholly-owned subsidiaries of Northern Powergrid participate in the Northern Powergrid group of the United Kingdom industry-wide Electricity Supply Pension Scheme (the "UK Plan"), which provides pension and other related defined benefits, based on final pensionable pay, to the majority of the employees of Northern Powergrid . The UK Plan is closed to employees hired after July 23, 1997. Employees hired after that date are covered by a defined contribution plan sponsored by a wholly-owned subsidiary of Northern Powergrid . Net Periodic Benefit Cost For purposes of calculating the expected return on pension plan assets, a market-related value is used. The market-related value of plan assets is calculated by spreading the difference between expected and actual investment returns over a five-year period beginning after the first year in which they occur. Net periodic benefit cost for the UK Plan included the following components for the years ended December 31 (in millions): 2016 2015 2014 Service cost $ 20 $ 24 $ 24 Interest cost 72 79 95 Expected return on plan assets (110 ) (116 ) (124 ) Net amortization 44 62 51 Net periodic benefit cost $ 26 $ 49 $ 46 Funded Status The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): 2016 2015 Plan assets at fair value, beginning of year $ 2,276 $ 2,368 Employer contributions 55 77 Participant contributions 1 2 Actual return on plan assets 349 48 Benefits paid (115 ) (91 ) Foreign currency exchange rate changes (397 ) (128 ) Plan assets at fair value, end of year $ 2,169 $ 2,276 The following table is a reconciliation of the benefit obligation for the years ended December 31 (in millions): 2016 2015 Benefit obligation, beginning of year $ 2,142 $ 2,279 Service cost 20 24 Interest cost 72 79 Participant contributions 1 2 Actuarial loss (gain) 387 (30 ) Benefits paid (115 ) (91 ) Foreign currency exchange rate changes (382 ) (121 ) Benefit obligation, end of year $ 2,125 $ 2,142 Accumulated benefit obligation, end of year $ 1,858 $ 1,891 The funded status of the UK Plan and the amounts recognized on the Consolidated Balance Sheets as of December 31 are as follows (in millions): 2016 2015 Plan assets at fair value, end of year $ 2,169 $ 2,276 Benefit obligation, end of year 2,125 2,142 Funded status $ 44 $ 134 Amounts recognized on the Consolidated Balance Sheets: Other assets $ 44 $ 134 Unrecognized Amounts The portion of the funded status of the UK Plan not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions): 2016 2015 Net loss $ 590 $ 592 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost, which are included in accumulated other comprehensive loss on the Consolidated Balance Sheets, for the years ended December 31 is as follows (in millions): 2016 2015 Balance, beginning of year $ 592 $ 655 Net loss arising during the year 148 38 Net amortization (44 ) (62 ) Foreign currency exchange rate changes (106 ) (39 ) Total (2 ) (63 ) Balance, end of year $ 590 $ 592 The net loss that will be amortized from accumulated other comprehensive loss in 2017 into net periodic benefit cost is estimated to be $65 million . Plan Assumptions Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: 2016 2015 2014 Benefit obligations as of December 31: Discount rate 2.70 % 3.70 % 3.60 % Rate of compensation increase 3.00 % 2.90 % 2.80 % Rate of future price inflation 3.00 % 2.90 % 2.80 % Net periodic benefit cost for the years ended December 31: Discount rate 3.70 % 3.60 % 4.40 % Expected return on plan assets 5.60 % 5.60 % 6.10 % Rate of compensation increase 2.90 % 2.80 % 3.15 % Rate of future price inflation 2.90 % 2.80 % 3.15 % Contributions and Benefit Payments Employer contributions to the UK Plan are expected to be £37 million during 2017 . The expected benefit payments to participants in the UK Plan for 2017 through 2021 and for the five years thereafter, using the foreign currency exchange rate as of December 31, 2016 , are summarized below (in millions): 2017 $ 75 2018 77 2019 79 2020 81 2021 83 2022-2026 448 Plan Assets Investment Policy and Asset Allocations The investment policy for the UK Plan is to balance risk and return through a diversified portfolio of debt securities, equity securities and real estate. Maturities for debt securities are managed to targets consistent with prudent risk tolerances. The UK Plan retains outside investment advisors to manage plan investments within the parameters set by the trustees of the UK Plan in consultation with Northern Powergrid . The investment portfolio is managed in line with the investment policy with sufficient liquidity to meet near-term benefit payments. The return on assets assumption is based on a weighted-average of the expected historical performance for the types of assets in which the UK Plan invests. The target allocations (percentage of plan assets) for the UK Plan assets are as follows as of December 31, 2016 : % Debt securities (1) 50-55 Equity securities (1) 35-40 Real estate funds and other 5-15 (1) For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds have been allocated based on the underlying investments in debt and equity securities. Fair Value Measurements The Company adopted ASU No. 2015-07, "Fair Value Measurement (Topic 820) - Disclosures for Investments in Certain Entities that Calculate Net Asset Value per Share (or its Equivalent)" effective January 1, 2016 under a retrospective method. The following table presents the fair value of the UK Plan assets, by major category, (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 4 $ 83 $ — $ 87 Debt securities: United Kingdom government obligations 718 — — 718 Equity securities: Investment funds (2) — 1,095 — 1,095 Real estate funds — — 105 105 Total $ 722 $ 1,178 $ 105 2,005 Investment funds (2) measured at net asset value 164 Total assets measured at fair value $ 2,169 As of December 31, 2015: Cash equivalents $ 46 $ — $ — $ 46 Debt securities: United Kingdom government obligations 424 — — 424 Other international government obligations — 13 — 13 Corporate obligations — 186 — 186 Equity securities: Investment funds (2) 24 1,189 — 1,213 Real estate funds — — 204 204 Total $ 494 $ 1,388 $ 204 2,086 Investment funds (2) measured at net asset value 190 Total assets measured at fair value $ 2,276 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 44% and 56% , respectively, for both 2016 and 2015 . The fair value of the UK Plan's assets are determined similar to the plan assets of the domestic plans as previously discussed. The following table reconciles the beginning and ending balances of the UK Plan assets measured at fair value using significant Level 3 inputs for the years ended December 31 (in millions): Real Estate Funds 2016 2015 2014 Beginning balance $ 204 $ 199 $ 179 Actual return on plan assets still held at period end 10 18 33 Sales (80 ) — — Foreign currency exchange rate changes (29 ) (13 ) (13 ) Ending balance $ 105 $ 204 $ 199 Defined Contribution Plans The Company sponsors various defined contribution plans covering substantially all employees. The Company's contributions vary depending on the plan, but matching contributions are based on each participant's level of contribution, and certain participants receive contributions based on eligible pre-tax annual compensation. Contributions cannot exceed the maximum allowable for tax purposes. The Company's contributions to these plans were $102 million , $90 million and $83 million for the years ended December 31, 2016 , 2015 and 2014 , respectively.
PacifiCorp [Member]
Defined Benefit Plan Disclosure [Line Items]
Employee Benefit Plans [Text Block]	Employee Benefit Plans PacifiCorp sponsors defined benefit pension and other postretirement benefit plans that cover the majority of its employees, as well as a defined contribution 401(k) employee savings plan ("401(k) Plan"). In addition, PacifiCorp contributes to a joint trustee pension plan and a subsidiary previously contributed to a multiemployer pension plan for benefits offered to certain bargaining units. Pension and Other Postretirement Benefit Plans PacifiCorp's pension plans include non-contributory defined benefit pension plans, collectively the PacifiCorp Retirement Plan ("Retirement Plan"), and the Supplemental Executive Retirement Plan ("SERP"). The Retirement Plan is closed to all non-union employees hired after January 1, 2008. All non-union Retirement Plan participants hired prior to January 1, 2008 that did not elect to receive equivalent fixed contributions to the 401(k) Plan effective January 1, 2009 earned benefits based on a cash balance formula through December 31, 2016. Effective January 1, 2017, non-union employee participants with a cash balance benefit in the Retirement Plan are no longer eligible to receive pay credits in their cash balance formula. In general for union employees, benefits under the Retirement Plan were frozen at various dates from December 31, 2007 through December 31, 2011 as they are now being provided with enhanced 401(k) Plan benefits. However, certain limited union Retirement Plan participants continue to earn benefits under the Retirement Plan based on the employee's years of service and a final average pay formula. The SERP was closed to new participants as of March 21, 2006 and froze future accruals for active participants as of December 31, 2014. PacifiCorp's other postretirement benefit plan provides healthcare and life insurance benefits to eligible retirees. Utah Mine Disposition and Labor Agreement In conjunction with the Utah Mine Disposition described in Note 5, in December 2014, PacifiCorp's subsidiary, Energy West Mining Company, reached a labor settlement with the UMWA covering union employees at PacifiCorp's Deer Creek mining operations. As a result of the labor settlement, the UMWA agreed to assume PacifiCorp's other postretirement benefit obligation associated with UMWA plan participants in exchange for PacifiCorp transferring $150 million to a fund managed by the UMWA. Transfer of the assets and settlement of this obligation occurred in May 2015 and resulted in a remeasurement of the other postretirement plan assets and benefit obligation. As a result of the remeasurement, PacifiCorp recognized a $9 million settlement loss, with the portion that is probable of recovery deferred as a regulatory asset. No curtailment accounting was triggered as a result of the settlement due to an insignificant impact to the average remaining service lives in the plan. As a result of the closure of the Deer Creek mining operations, withdrawal from the UMWA 1974 Pension Plan was involuntarily triggered in June 2015 when UMWA employees ceased performing work for the subsidiary. Refer to "Multiemployer and Joint Trustee Pension Plans" for further information regarding the withdrawal. Net Periodic Benefit Cost For purposes of calculating the expected return on plan assets, a market-related value is used. The market-related value of plan assets is calculated by spreading the difference between expected and actual investment returns over a five-year period beginning after the first year in which they occur. Net periodic benefit cost for the plans included the following components for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Service cost $ 4 $ 4 $ 5 $ 2 $ 3 $ 6 Interest cost 54 53 57 15 16 28 Expected return on plan assets (75 ) (77 ) (76 ) (21 ) (23 ) (31 ) Net amortization 34 42 29 (5 ) (4 ) 2 Net periodic benefit cost (credit) $ 17 $ 22 $ 15 $ (9 ) $ (8 ) $ 5 Funded Status The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, beginning of year $ 1,043 $ 1,146 $ 305 $ 482 Employer contributions 5 4 1 1 Participant contributions — — 6 6 Actual return on plan assets 51 — 17 1 Settlement — — — (150 ) Benefits paid (100 ) (107 ) (27 ) (35 ) Plan assets at fair value, end of year $ 999 $ 1,043 $ 302 $ 305 The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Benefit obligation, beginning of year $ 1,289 $ 1,378 $ 362 $ 539 Service cost 4 4 2 3 Interest cost 54 53 15 16 Participant contributions — — 6 6 Actuarial (gain) loss 29 (39 ) — (17 ) Settlement — — — (150 ) Benefits paid (100 ) (107 ) (27 ) (35 ) Benefit obligation, end of year $ 1,276 $ 1,289 $ 358 $ 362 Accumulated benefit obligation, end of year $ 1,276 $ 1,289 The funded status of the plans and the amounts recognized on the Consolidated Balance Sheets as of December 31 are as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, end of year $ 999 $ 1,043 $ 302 $ 305 Less - Benefit obligation, end of year 1,276 1,289 358 362 Funded status $ (277 ) $ (246 ) $ (56 ) $ (57 ) Amounts recognized on the Consolidated Balance Sheets: Other current liabilities $ (5 ) $ (4 ) $ — $ — Other long-term liabilities (272 ) (242 ) (56 ) (57 ) Amounts recognized $ (277 ) $ (246 ) $ (56 ) $ (57 ) The SERP has no plan assets; however, PacifiCorp has a Rabbi trust that holds corporate-owned life insurance and other investments to provide funding for the future cash requirements of the SERP. The cash surrender value of all of the policies included in the Rabbi trust, net of amounts borrowed against the cash surrender value, plus the fair market value of other Rabbi trust investments, was $55 million and $52 million as of December 31, 2016 and 2015 , respectively. These assets are not included in the plan assets in the above table, but are reflected in noncurrent other assets on the Consolidated Balance Sheets. Unrecognized Amounts The portion of the funded status of the plans not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Net loss $ 518 $ 508 $ 39 $ 36 Prior service credit — (13 ) (13 ) (19 ) Regulatory deferrals (7 ) (3 ) 8 9 Total $ 511 $ 492 $ 34 $ 26 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2016 and 2015 is as follows (in millions): Accumulated Other Regulatory Comprehensive Asset Loss Total Pension Balance, December 31, 2014 $ 474 $ 22 $ 496 Net loss (gain) arising during the year 40 (2 ) 38 Net amortization (41 ) (1 ) (42 ) Total (1 ) (3 ) (4 ) Balance, December 31, 2015 473 19 492 Net loss arising during the year 51 2 53 Net amortization (33 ) (1 ) (34 ) Total 18 1 19 Balance, December 31, 2016 $ 491 $ 20 $ 511 Regulatory Asset Other Postretirement Balance, December 31, 2014 $ 17 Net loss arising during the year 5 Net amortization 4 Total 9 Balance, December 31, 2015 26 Net loss arising during the year 3 Net amortization 5 Total 8 Balance, December 31, 2016 $ 34 The net loss, prior service credit and regulatory deferrals that will be amortized in 2017 into net periodic benefit cost are estimated to be as follows (in millions): Net Prior Service Regulatory Loss Credit Deferrals Total Pension $ 16 $ — $ (2 ) $ 14 Other postretirement — (7 ) 1 (6 ) Total $ 16 $ (7 ) $ (1 ) $ 8 Plan Assumptions Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Benefit obligations as of December 31: Discount rate 4.05 % 4.40 % 4.00 % 4.05 % 4.35 % 3.90 % Rate of compensation increase N/A 2.75 2.75 N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.40 % 4.00 % 4.80 % 4.35 % 3.99 % 4.90 % Expected return on plan assets 7.50 7.50 7.50 7.50 7.08 7.50 Rate of compensation increase 2.75 2.75 3.00 N/A N/A N/A In establishing its assumption as to the expected return on plan assets, PacifiCorp utilizes the asset allocation and return assumptions for each asset class based on historical performance and forward-looking views of the financial markets. As discussed above in "Utah Mine Disposition and Labor Agreement," PacifiCorp remeasured the other postretirement plan assets and benefit obligation as of May 31, 2015. The other postretirement assumptions for the year ended December 31, 2015 presented above reflect a weighted average calculation that considered the assumptions used in the periods preceding and subsequent to the remeasurement. As a result of a plan amendment effective on January 1, 2017, the benefit obligation for the Retirement Plan is no longer affected by future increases in compensation. As a result of the labor settlement discussed above in "Utah Mine Disposition and Labor Agreement," the benefit obligation for the other postretirement plan is no longer affected by healthcare cost trends. Contributions and Benefit Payments Employer contributions to the pension and other postretirement benefit plans are expected to be $5 million and $- million, respectively, during 2017 . Funding to PacifiCorp's Retirement Plan trust is based upon the actuarially determined costs of the plan and the requirements of the Internal Revenue Code, the Employee Retirement Income Security Act of 1974 ("ERISA") and the Pension Protection Act of 2006, as amended ("PPA"). PacifiCorp considers contributing additional amounts from time to time in order to achieve certain funding levels specified under the PPA. PacifiCorp's funding policy for its other postretirement benefit plan is to generally contribute an amount equal to the net periodic benefit cost, subject to tax deductibility limitations and other considerations. The expected benefit payments to participants in PacifiCorp's pension and other postretirement benefit plans for 2017 through 2021 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Pension Other Postretirement 2017 $ 105 $ 28 2018 109 28 2019 108 27 2020 104 30 2021 97 26 2022-2026 426 116 Plan Assets Investment Policy and Asset Allocations PacifiCorp's investment policy for its pension and other postretirement benefit plans is to balance risk and return through a diversified portfolio of debt securities, equity securities and other alternative investments. Maturities for debt securities are managed to targets consistent with prudent risk tolerances. The plans retain outside investment advisors to manage plan investments within the parameters outlined by the PacifiCorp Pension Committee. The investment portfolio is managed in line with the investment policy with sufficient liquidity to meet near-term benefit payments. The target allocations (percentage of plan assets) for PacifiCorp's pension and other postretirement benefit plan assets are as follows as of December 31, 2016 : Pension (1) Other Postretirement (1) % % Debt securities (2) 33 - 37 33 - 37 Equity securities (2) 53 - 57 61 - 65 Limited partnership interests 8 - 12 1 - 3 Other 0 - 1 0 - 1 (1) PacifiCorp's Retirement Plan trust includes a separate account that is used to fund benefits for the other postretirement benefit plan. In addition to this separate account, the assets for the other postretirement benefit plan are held in Voluntary Employees' Beneficiary Association ("VEBA") trusts, each of which has its own investment allocation strategies. Target allocations for the other postretirement benefit plan include the separate account of the Retirement Plan trust and the VEBA trusts. (2) For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities. Fair Value Measurements PacifiCorp adopted ASU No. 2015-07, "Fair Value Measurement (Topic 820) - Disclosures for Investments in Certain Entities that Calculate Net Asset Value per Share (or its Equivalent)" effective January 1, 2016 under a retrospective method. The following table presents the fair value of plan assets, by major category, for PacifiCorp's defined benefit pension plan (in millions): Input Levels for Fair Value Measurements Level 1 (1) Level 2 (1) Level 3 (1) Total As of December 31, 2016: Cash equivalents $ — $ 10 $ — $ 10 Debt securities: United States government obligations 25 — — 25 Corporate obligations — 36 — 36 Municipal obligations — 6 — 6 Agency, asset and mortgage-backed obligations — 37 — 37 Equity securities: United States companies 389 — — 389 International companies 15 — — 15 Investment funds (2) 83 — — 83 Total assets in the fair value hierarchy $ 512 $ 89 $ — 601 Investment funds (2) measured at net asset value 337 Limited partnership interests (3) measured at net asset value 61 Investments at fair value $ 999 As of December 31, 2015: Cash equivalents $ — $ 10 $ — $ 10 Debt securities: United States government obligations 19 — — 19 Corporate obligations — 42 — 42 Municipal obligations — 5 — 5 Agency, asset and mortgage-backed obligations — 43 — 43 Equity securities: United States companies 408 — — 408 International companies 17 — — 17 Investment funds (2) 83 — — 83 Total assets in the fair value hierarchy $ 527 $ 100 $ — 627 Investment funds (2) measured at net asset value 351 Limited partnership interests (3) measured at net asset value 65 Investments at fair value $ 1,043 (1) Refer to Note 12 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are substantially comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 54% and 46% respectively, for 2016 and 53% and 47% , respectively, for 2015 , and are invested in United States and international securities of approximately 39% and 61% , respectively, for 2016 and 40% and 60% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. The following table presents the fair value of plan assets, by major category, for PacifiCorp's defined benefit other postretirement plan (in millions): Input Levels for Fair Value Measurements Level 1 (1) Level 2 (1) Level 3 (1) Total As of December 31, 2016: Cash and cash equivalents $ 4 $ 1 $ — $ 5 Debt securities: United States government obligations 11 — — 11 Corporate obligations — 13 — 13 Municipal obligations — 2 — 2 Agency, asset and mortgage-backed obligations — 13 — 13 Equity securities: United States companies 93 — — 93 International companies 4 — — 4 Investment funds (2) 32 — — 32 Total assets in the fair value hierarchy $ 144 $ 29 $ — 173 Investment funds (2) measured at net asset value 125 Limited partnership interests (3) measured at net asset value 4 Investments at fair value $ 302 As of December 31, 2015: Cash and cash equivalents $ 4 $ 1 $ — $ 5 Debt securities: United States government obligations 9 — — 9 Corporate obligations — 15 — 15 Municipal obligations — 1 — 1 Agency, asset and mortgage-backed obligations — 14 — 14 Equity securities: United States companies 95 — — 95 International companies 4 — — 4 Investment funds (2) 32 — — 32 Total assets in the fair value hierarchy $ 144 $ 31 $ — 175 Investment funds (2) measured at net asset value 126 Limited partnership interests (3) measured at net asset value 4 Investments at fair value $ 305 (1) Refer to Note 12 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are substantially comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 62% and 38% , respectively, for 2016 and 61% and 39% , respectively, for 2015 , and are invested in United States and international securities of approximately 71% and 29% , respectively, for 2016 and 67% and 33% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. For level 1 investments, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. For level 2 investments, the fair value is determined using pricing models based on observable market inputs. Shares of mutual funds not registered under the Securities Act of 1933, private equity limited partnership interests, common and commingled trust funds and investment entities are reported at fair value based on the net asset value per unit, which is used for expedience purposes. A fund’s net asset value is based on the fair value of the underlying assets held by the fund less its liabilities. Multiemployer and Joint Trustee Pension Plans PacifiCorp contributes to the PacifiCorp/IBEW Local 57 Retirement Trust Fund ("Local 57 Trust Fund") (plan number 001) and its subsidiary, Energy West Mining Company, previously contributed to the UMWA 1974 Pension Plan (plan number 002). Contributions to these pension plans are based on the terms of collective bargaining agreements. As a result of the Utah Mine Disposition and UMWA labor settlement, PacifiCorp's subsidiary, Energy West Mining Company, triggered involuntary withdrawal from the UMWA 1974 Pension Plan in June 2015 when the UMWA employees ceased performing work for the subsidiary. PacifiCorp recorded its estimate of the withdrawal obligation in December 2014 when withdrawal was considered probable and deferred the portion of the obligation considered probable of recovery to a regulatory asset. PacifiCorp has subsequently revised its estimate due to changes in facts and circumstances for a withdrawal occurring by July 2015. As communicated in a letter received in August 2016, the plan trustees have determined a withdrawal liability of $115 million . Energy West Mining Company began making installment payments in November 2016 and has the option to elect a lump sum payment to settle the withdrawal obligation. The ultimate amount paid by Energy West Mining Company to settle the obligation is dependent on a variety of factors, including the results of ongoing negotiations with the plan trustees. The Local 57 Trust Fund is a joint trustee plan such that the board of trustees is represented by an equal number of trustees from PacifiCorp and the union. The Local 57 Trust Fund was established pursuant to the provisions of the Taft-Hartley Act and although formed with the ability for other employers to participate in the plan, there are no other employers that participate in this plan. The risk of participating in multiemployer pension plans generally differs from single-employer plans in that assets are pooled such that contributions by one employer may be used to provide benefits to employees of other participating employers and plan assets cannot revert back to employers. If an employer ceases participation in the plan, the employer may be obligated to pay a withdrawal liability based on the participants' unfunded, vested benefits in the plan. This occurred as a result of Energy West Mining Company's withdrawal from the UMWA 1974 Pension Plan. If participating employers withdraw from a multiemployer plan, the unfunded obligations of the plan may be borne by the remaining participating employers, including any employers that withdrew during the three years prior to a mass withdrawal. The following table presents PacifiCorp's and Energy West Mining Company's participation in individually significant joint trustee and multiemployer pension plans for the years ended December 31 (dollars in millions): PPA zone status or plan funded status percentage for plan years beginning July 1, Contributions (1) Plan name Employer Identification Number 2016 2015 2014 Funding improvement plan Surcharge imposed under PPA (1) 2016 2015 2014 Year contributions to plan exceeded more than 5% of total contributions (2) UMWA 1974 Pension Plan 52-1050282 Critical and Declining Critical and Declining Critical Implemented Yes $ — $ 1 $ 2 None Local 57 Trust Fund 87-0640888 At least 80% At least 80% At least 80% None None $ 8 $ 8 $ 9 2015, 2014, 2013 (1) PacifiCorp's and Energy West Mining Company's minimum contributions to the plans are based on the amount of wages paid to employees covered by the Local 57 Trust Fund collective bargaining agreements and the number of mining hours worked for the UMWA 1974 Pension Plan, respectively, subject to ERISA minimum funding requirements. As a result of the plan's critical status, Energy West Mining Company was required to begin paying a surcharge for hours worked on and after December 1, 2014. (2) For the UMWA 1974 Pension Plan, information is for plan years beginning July 1, 2014, 2013 and 2012. Information for the plan year beginning July 1, 2015 is not yet available. For the Local 57 Trust Fund, information is for plan years beginning July 1, 2014, 2013 and 2012. Information for the plan year beginning July 1, 2015 is not yet available. The current collective bargaining agreements governing the Local 57 Trust Fund expire in 2020. Defined Contribution Plan PacifiCorp's 401(k) plan covers substantially all employees. PacifiCorp's matching contributions are based on each participant's level of contribution and, as of January 1, 2017, all participants receive contributions based on eligible pre-tax annual compensation. Contributions cannot exceed the maximum allowable for tax purposes. PacifiCorp's contributions to the 401(k) plan were $34 million , $35 million and $34 million for the years ended December 31, 2016 , 2015 and 2014 , respectively.
MidAmerican Energy Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Employee Benefit Plans [Text Block]	Employee Benefit Plans MidAmerican Energy sponsors a noncontributory defined benefit pension plan covering a majority of all employees of BHE and its domestic energy subsidiaries other than PacifiCorp and NV Energy, Inc. Benefit obligations under the plan are based on a cash balance arrangement for salaried employees and most union employees and final average pay formulas for other union employees. MidAmerican Energy also maintains noncontributory, nonqualified defined benefit supplemental executive retirement plans ("SERP") for certain active and retired participants. MidAmerican Energy also sponsors certain postretirement healthcare and life insurance benefits covering substantially all retired employees of BHE and its domestic energy subsidiaries other than PacifiCorp and NV Energy, Inc. Under the plans, a majority of all employees of the participating companies may become eligible for these benefits if they reach retirement age. New employees are not eligible for benefits under the plans. MidAmerican Energy has been allowed to recover accrued pension and other postretirement benefit costs in its electric and gas service rates. Net Periodic Benefit Cost For purposes of calculating the expected return on pension plan assets, a market-related value is used. The market-related value of plan assets is calculated by spreading the difference between expected and actual investment returns on equity investments over a five-year period beginning after the first year in which they occur. MidAmerican Energy bills to and is reimbursed currently for affiliates' share of the net periodic benefit costs from all plans in which such affiliates participate. In 2016 , 2015 and 2014 , MidAmerican Energy's share of the pension net periodic benefit cost (credit) was $(2) million , $(4) million and $1 million , respectively. MidAmerican Energy's share of the other postretirement net periodic benefit cost (credit) in 2016 , 2015 and 2014 totaled $(1) million , $- million and $- million, respectively. Net periodic benefit cost for the plans of MidAmerican Energy and the aforementioned affiliates included the following components for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Service cost $ 10 $ 12 $ 14 $ 5 $ 7 $ 6 Interest cost 34 32 35 10 9 10 Expected return on plan assets (44 ) (46 ) (45 ) (13 ) (15 ) (15 ) Net amortization 2 2 1 (4 ) (3 ) (3 ) Net periodic benefit cost (credit) $ 2 $ — $ 5 $ (2 ) $ (2 ) $ (2 ) Funded Status The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, beginning of year $ 678 $ 730 $ 249 $ 259 Employer contributions 7 7 1 1 Participant contributions — — 1 1 Actual return on plan assets 57 4 14 — Benefits paid (58 ) (63 ) (13 ) (12 ) Plan assets at fair value, end of year $ 684 $ 678 $ 252 $ 249 The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Benefit obligation, beginning of year $ 785 $ 840 $ 234 $ 249 Service cost 10 12 5 7 Interest cost 34 32 10 9 Participant contributions — — 1 1 Actuarial loss (gain) 2 (36 ) (4 ) (20 ) Benefits paid (58 ) (63 ) (13 ) (12 ) Benefit obligation, end of year $ 773 $ 785 $ 233 $ 234 Accumulated benefit obligation, end of year $ 764 $ 773 The funded status of the plans and the amounts recognized on the Balance Sheets as of December 31 are as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, end of year $ 684 $ 678 $ 252 $ 249 Less - Benefit obligation, end of year 773 785 233 234 Funded status $ (89 ) $ (107 ) $ 19 $ 15 Amounts recognized on the Balance Sheets: Other assets $ 26 $ 7 $ 19 $ 15 Other current liabilities (8 ) (8 ) — — Other liabilities (107 ) (106 ) — — Amounts recognized $ (89 ) $ (107 ) $ 19 $ 15 The SERP has no plan assets; however, MidAmerican Energy and BHE have Rabbi trusts that hold corporate-owned life insurance and other investments to provide funding for the future cash requirements of the SERP. The cash surrender value of all of the policies included in the Rabbi trusts, net of amounts borrowed against the cash surrender value, plus the fair market value of other Rabbi trust investments, was $166 million and $156 million as of December 31, 2016 and 2015 , respectively, of which $110 million and $104 million was held by MidAmerican Energy as of December 31, 2016 and 2015 , respectively, with the remainder held by BHE. These assets are not included in the plan assets in the above table, but are reflected in investments and nonregulated property, net on the Balance Sheets. Unrecognized Amounts The portion of the funded status of the plans not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Net loss $ 15 $ 26 $ 36 $ 42 Prior service cost (credit) 1 2 (31 ) (36 ) Total $ 16 $ 28 $ 5 $ 6 MidAmerican Energy sponsors pension and other postretirement benefit plans on behalf of certain of its affiliates in addition to itself, and therefore, the portion of the funded status of the respective plans that has not yet been recognized in net periodic benefit cost is attributable to multiple entities. Additionally, substantially all of MidAmerican Energy's portion of such amounts is either refundable to or recoverable from its customers and is reflected as regulatory liabilities and regulatory assets. A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2016 and 2015 is as follows (in millions): Regulatory Asset Regulatory Liability Receivables (Payables) with Affiliates Total Pension Balance, December 31, 2014 $ 22 $ (5 ) $ 7 $ 24 Net loss (gain) arising during the year 2 5 (1 ) 6 Net amortization (2 ) — — (2 ) Total — 5 (1 ) 4 Balance, December 31, 2015 22 — 6 28 Net gain arising during the year 1 (11 ) — (10 ) Net amortization (1 ) (1 ) — (2 ) Total — (12 ) — (12 ) Balance, December 31, 2016 $ 22 $ (12 ) $ 6 $ 16 Regulatory Asset Regulatory Liability Receivables (Payables) with Affiliates Total Other Postretirement Balance, December 31, 2014 $ 20 $ — $ (13 ) $ 7 Net gain arising during the year (5 ) — — (5 ) Net amortization 2 — 2 4 Total (3 ) — 2 (1 ) Balance, December 31, 2015 17 — (11 ) 6 Net gain arising during the year (2 ) — (3 ) (5 ) Net amortization 3 — 1 4 Total 1 — (2 ) (1 ) Balance, December 31, 2016 $ 18 $ — $ (13 ) $ 5 The net loss and prior service cost (credit) that will be amortized in 2017 into net periodic benefit cost are estimated to be as follows (in millions): Net Loss Prior Service Cost (Credit) Total Pension $ 1 $ 1 $ 2 Other postretirement 2 (6 ) (4 ) Total $ 3 $ (5 ) $ (2 ) Plan Assumptions Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Benefit obligations as of December 31: Discount rate 4.10 % 4.50 % 4.00 % 3.90 % 4.25 % 3.75 % Rate of compensation increase 2.75 % 2.75 % 2.75 % N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.50 % 4.00 % 4.75 % 4.25 % 3.75 % 4.50 % Expected return on plan assets (1) 7.00 % 7.25 % 7.50 % 6.75 % 7.00 % 7.25 % Rate of compensation increase 2.75 % 2.75 % 3.00 % N/A N/A N/A (1) Amounts reflected are pre-tax values. Assumed after-tax returns for a taxable, non-union other postretirement plan were 5.00% for 2016 , and 5.18% for 2015 , and 5.37% for 2014 . In establishing its assumption as to the expected return on plan assets, MidAmerican Energy utilizes the asset allocation and return assumptions for each asset class based on historical performance and forward-looking views of the financial markets. 2016 2015 Assumed healthcare cost trend rates as of December 31: Healthcare cost trend rate assumed for next year 7.40 % 7.70 % Rate that the cost trend rate gradually declines to 5.00 % 5.00 % Year that the rate reaches the rate it is assumed to remain at 2025 2025 A one percentage-point change in assumed healthcare cost trend rates would have the following effects (in millions): One Percentage-Point Increase Decrease Increase (decrease) in: Total service and interest cost for the year ended December 31, 2016 $ — $ — Other postretirement benefit obligation as of December 31, 2016 3 (2 ) Contributions and Benefit Payments Employer contributions to the pension and other postretirement benefit plans are expected to be $8 million and $1 million , respectively, during 2017 . Funding to MidAmerican Energy's pension benefit plan trust is based upon the actuarially determined costs of the plan and the requirements of the Internal Revenue Code, the Employee Retirement Income Security Act of 1974 and the Pension Protection Act of 2006, as amended. MidAmerican Energy considers contributing additional amounts from time to time in order to achieve certain funding levels specified under the Pension Protection Act of 2006, as amended. MidAmerican Energy's funding policy for its other postretirement benefit plan is to generally contribute amounts consistent with its rate regulatory arrangements. Net periodic benefit costs assigned to MidAmerican Energy affiliates are reimbursed currently in accordance with its intercompany administrative services agreement. The expected benefit payments to participants in MidAmerican Energy's pension and other postretirement benefit plans for 2017 through 2021 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Pension Other Postretirement 2017 $ 60 $ 18 2018 60 19 2019 62 20 2020 62 21 2021 60 21 2022-2026 278 97 Plan Assets Investment Policy and Asset Allocations MidAmerican Energy's investment policy for its pension and other postretirement benefit plans is to balance risk and return through a diversified portfolio of debt securities, equity securities and other alternative investments. Maturities for debt securities are managed to targets consistent with prudent risk tolerances. The plans retain outside investment advisors to manage plan investments within the parameters outlined by the MidAmerican Energy Pension and Employee Benefits Plans Administrative Committee. The investment portfolio is managed in line with the investment policy with sufficient liquidity to meet near-term benefit payments. The target allocations (percentage of plan assets) for MidAmerican Energy's pension and other postretirement benefit plan assets are as follows as of December 31, 2016 : Pension Other Postretirement % % Debt securities (1) 20-40 25-45 Equity securities (1) 60-80 50-80 Real estate funds 2-8 — Other 0-5 0-5 (1) For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities. Fair Value Measurements MidAmerican Energy adopted ASU No. 2015-07, "Fair Value Measurement (Topic 820) - Disclosures for Investments in Certain Entities that Calculate Net Asset Value per Share (or its Equivalent)" effective January 1, 2016 under a retrospective method. The following table presents the fair value of plan assets, by major category, for MidAmerican Energy's defined benefit pension plan (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ — $ 17 $ — $ 17 Debt securities: United States government obligations 9 — — 9 Corporate obligations — 53 — 53 Municipal obligations — 6 — 6 Agency, asset and mortgage-backed obligations — 22 — 22 Equity securities: United States companies 130 — — 130 International equity securities 39 — — 39 Investment funds (2) 63 — — 63 Total assets in the hierarchy $ 241 $ 98 $ — 339 Investment funds (2) measured at net asset value 295 Real estate funds measured at net asset value 50 Total assets measured at fair value $ 684 As of December 31, 2015: Cash equivalents $ — $ 16 $ — $ 16 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 57 — 57 Municipal obligations — 6 — 6 Agency, asset and mortgage-backed obligations — 27 — 27 Equity securities: United States companies 130 — — 130 International equity securities 40 — — 40 Investment funds (2) 61 — — 61 Total assets in the hierarchy $ 236 $ 106 $ — 342 Investment funds (2) measured at net asset value 296 Real estate funds measured at net asset value 40 Total assets measured at fair value $ 678 (1) Refer to Note 14 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 74% and 26% , respectively, for 2016 and 72% and 28% , respectively, for 2015 . Additionally, these funds are invested in United States and international securities of approximately 71% and 29% , respectively, for 2016 and 73% and 27% , respectively, for 2015 . The following table presents the fair value of plan assets, by major category, for MidAmerican Energy's defined benefit other postretirement plans (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 10 $ — $ — $ 10 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 11 — 11 Municipal obligations — 37 — 37 Agency, asset and mortgage-backed obligations — 11 — 11 Equity securities: United States companies 122 — — 122 Investment funds (2) 56 — — 56 Total assets measured at fair value $ 193 $ 59 $ — $ 252 As of December 31, 2015: Cash equivalents $ 5 $ — $ — $ 5 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 12 — 12 Municipal obligations — 39 — 39 Agency, asset and mortgage-backed obligations — 12 — 12 Equity securities: United States companies 120 — — 120 Investment funds (2) 56 — — 56 Total assets measured at fair value $ 186 $ 63 $ — $ 249 (1) Refer to Note 14 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 70% and 30% , respectively, for 2016 and 68% and 32% , respectively, for 2015 . Additionally, these funds are invested in United States and international securities of approximately 30% and 70% , respectively, for 2016 and 32% and 68% , respectively, for 2015 . For level 1 investments, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. For level 2 investments, the fair value is determined using pricing models based on observable market inputs. Shares of mutual funds not registered under the Securities Act of 1933, private equity limited partnership interests, common and commingled trust funds and investment entities are reported at fair value based on the net asset value per unit, which is used for expedience purposes. A fund’s net asset value is based on the fair value of the underlying assets held by the fund less its liabilities. MidAmerican Energy sponsors a defined contribution plan ("401(k) plan") covering substantially all employees. MidAmerican Energy's matching contributions are based on each participant's level of contribution, and certain participants receive contributions based on eligible pre-tax annual compensation. Contributions cannot exceed the maximum allowable for tax purposes. Certain participants now receive enhanced benefits in the 401(k) plan and no longer accrue benefits in the noncontributory defined benefit pension plans. MidAmerican Energy's contributions to the plan were $20 million , $20 million , and $19 million for the years ended December 31, 2016 , 2015 and 2014 , respectively.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Defined Benefit Plan Disclosure [Line Items]
Employee Benefit Plans [Text Block]	Employee Benefit Plans Refer to Note 11 of MidAmerican Energy's Notes to Financial Statements for additional information regarding MidAmerican Funding's pension, supplemental retirement and postretirement benefit plans. Pension and postretirement costs allocated by MidAmerican Funding to its parent and other affiliates in each of the years ended December 31, were as follows (in millions): 2016 2015 2014 Pension costs $ 4 $ 4 $ 4 Other postretirement costs (1 ) (2 ) (2 )

Retirement Plan and Postretirem

Retirement Plan and Postretirement Benefits Retirement Plan and Postretirement Benefits (Notes)	12 Months Ended
	Dec. 31, 2016
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employee Benefit Plans [Text Block]	Employee Benefit Plans Defined Benefit Plans Domestic Operations The Utilities sponsor defined benefit pension plans that cover a majority of all employees of BHE and its domestic energy subsidiaries. These pension plans include noncontributory defined benefit pension plans, supplemental executive retirement plans ("SERP") and a restoration plan for certain executives of NV Energy. The Utilities also provide certain postretirement healthcare and life insurance benefits through various plans to eligible retirees. Net Periodic Benefit Cost For purposes of calculating the expected return on plan assets, a market-related value is used. The market-related value of plan assets is calculated by spreading the difference between expected and actual investment returns over a five-year period beginning after the first year in which they occur. Net periodic benefit cost for the plans included the following components for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Service cost $ 29 $ 33 $ 36 $ 9 $ 11 $ 14 Interest cost 126 121 131 31 31 46 Expected return on plan assets (160 ) (169 ) (164 ) (41 ) (45 ) (53 ) Net amortization 46 53 44 (12 ) (11 ) (3 ) Net periodic benefit cost (credit) $ 41 $ 38 $ 47 $ (13 ) $ (14 ) $ 4 Funded Status The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, beginning of year $ 2,489 $ 2,718 $ 662 $ 858 Employer contributions 78 13 2 2 Participant contributions — — 10 9 Actual return on plan assets 163 (17 ) 41 — Settlement (11 ) (23 ) — (150 ) Benefits paid (194 ) (202 ) (49 ) (57 ) Plan assets at fair value, end of year $ 2,525 $ 2,489 $ 666 $ 662 The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Benefit obligation, beginning of year $ 2,934 $ 3,119 $ 740 $ 936 Service cost 29 33 9 11 Interest cost 126 121 31 31 Participant contributions — — 10 9 Actuarial loss (gain) 67 (110 ) (7 ) (43 ) Amendment 1 (4 ) — 3 Settlement (11 ) (23 ) — (150 ) Benefits paid (194 ) (202 ) (49 ) (57 ) Benefit obligation, end of year $ 2,952 $ 2,934 $ 734 $ 740 Accumulated benefit obligation, end of year $ 2,929 $ 2,906 In December 2014, PacifiCorp's subsidiary, Energy West Mining Company, reached a labor settlement with the UMWA covering union employees at PacifiCorp's Deer Creek mining operations. As a result of the labor settlement, the UMWA agreed to assume PacifiCorp's other postretirement benefit obligation associated with UMWA plan participants in exchange for PacifiCorp transferring $150 million to a fund managed by the UMWA. Transfer of the assets and settlement of this obligation occurred in May 2015 and resulted in a remeasurement of the other postretirement plan assets and benefit obligation. As a result of the remeasurement, PacifiCorp recognized a $9 million settlement loss, with the portion that is probable of recovery deferred as a regulatory asset. No curtailment accounting was triggered as a result of the settlement due to an insignificant impact to the average remaining service lives in the plan. The funded status of the plans and the amounts recognized on the Consolidated Balance Sheets as of December 31 are as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, end of year $ 2,525 $ 2,489 $ 666 $ 662 Benefit obligation, end of year 2,952 2,934 734 740 Funded status $ (427 ) $ (445 ) $ (68 ) $ (78 ) Amounts recognized on the Consolidated Balance Sheets: Other assets $ 26 $ 7 $ 19 $ 15 Other current liabilities (15 ) (15 ) — — Other long-term liabilities (438 ) (437 ) (87 ) (93 ) Amounts recognized $ (427 ) $ (445 ) $ (68 ) $ (78 ) The SERPs and restoration plan have no plan assets; however, the Company has Rabbi trusts that hold corporate-owned life insurance and other investments to provide funding for the future cash requirements of the SERPs and restoration plan. The cash surrender value of all of the policies included in the Rabbi trusts, net of amounts borrowed against the cash surrender value, plus the fair market value of other Rabbi trust investments, was $242 million and $228 million as of December 31, 2016 and 2015 , respectively. These assets are not included in the plan assets in the above table, but are reflected in noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of plan assets, projected benefit obligation and accumulated benefit obligation for (1) pension and other postretirement benefit plans with a projected benefit obligation in excess of the fair value of plan assets and (2) pension plans with an accumulated benefit obligation in excess of the fair value of plan assets as of December 31 are as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Fair value of plan assets $ 1,841 $ 1,811 $ 413 $ 413 Projected benefit obligation $ 2,294 $ 2,263 $ 500 $ 505 Accumulated benefit obligation $ 2,278 $ 2,244 Unrecognized Amounts The portion of the funded status of the plans not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Net loss $ 775 $ 768 $ 88 $ 97 Prior service credit (7 ) (25 ) (52 ) (68 ) Regulatory deferrals (7 ) (2 ) 7 8 Total $ 761 $ 741 $ 43 $ 37 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2016 and 2015 is as follows (in millions): Accumulated Other Regulatory Regulatory Comprehensive Asset Liability Loss Total Pension Balance, December 31, 2014 $ 710 $ (6 ) $ 19 $ 723 Net loss (gain) arising during the year 76 5 (6 ) 75 Net prior service credit arising during the year (4 ) — — (4 ) Net amortization (53 ) — — (53 ) Total 19 5 (6 ) 18 Balance, December 31, 2015 729 (1 ) 13 741 Net loss arising during the year 76 (11 ) — 65 Net prior service cost arising during the year 1 — — 1 Net amortization (45 ) (1 ) — (46 ) Total 32 (12 ) — 20 Balance, December 31, 2016 $ 761 $ (13 ) $ 13 $ 761 Regulatory Regulatory Asset Liability Total Other Postretirement Balance, December 31, 2014 $ 37 $ (14 ) $ 23 Net (gain) loss arising during the year (1 ) 1 — Net prior service cost arising during the year 3 — 3 Net amortization 10 1 11 Total 12 2 14 Balance, December 31, 2015 49 (12 ) 37 Net gain arising during the year (5 ) (1 ) (6 ) Net amortization 11 1 12 Total 6 — 6 Balance, December 31, 2016 $ 55 $ (12 ) $ 43 The net loss, prior service credit and regulatory deferrals that will be amortized in 2017 into net periodic benefit cost are estimated to be as follows (in millions): Net Prior Service Regulatory Loss Credit Deferrals Total Pension $ 33 $ (3 ) $ (2 ) $ 28 Other postretirement 2 (16 ) 1 (13 ) Total $ 35 $ (19 ) $ (1 ) $ 15 Plan Assumptions Weighted-average assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Benefit obligations as of December 31: Discount rate 4.06 % 4.43 % 4.00 % 4.01 % 4.33 % 3.88 % Rate of compensation increase 2.75 % 2.75 % 2.75 % N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.43 % 4.00 % 4.81 % 4.33 % 3.93 % 4.82 % Expected return on plan assets 6.78 % 6.88 % 6.86 % 7.03 % 7.00 % 7.34 % Rate of compensation increase 2.75 % 2.75 % 3.00 % N/A N/A N/A In establishing its assumption as to the expected return on plan assets, the Company utilizes the asset allocation and return assumptions for each asset class based on historical performance and forward-looking views of the financial markets. 2016 2015 Assumed healthcare cost trend rates as of December 31: Healthcare cost trend rate assumed for next year 7.40 % 7.70 % Rate that the cost trend rate gradually declines to 5.00 % 5.00 % Year that the rate reaches the rate it is assumed to remain at 2025 2025 A one percentage-point change in assumed healthcare cost trend rates would have the following effects (in millions): One Percentage-Point Increase Decrease Increase (decrease) in: Total service and interest cost for the year ended December 31, 2016 $ 1 $ — Other postretirement benefit obligation as of December 31, 2016 4 (4 ) Contributions and Benefit Payments Employer contributions to the pension and other postretirement benefit plans are expected to be $14 million and $4 million , respectively, during 2017 . Funding to the established pension trusts is based upon the actuarially determined costs of the plans and the requirements of the Internal Revenue Code, the Employee Retirement Income Security Act of 1974 and the Pension Protection Act of 2006, as amended. The Company considers contributing additional amounts from time to time in order to achieve certain funding levels specified under the Pension Protection Act of 2006, as amended. The Company's funding policy for its other postretirement benefit plans is to generally contribute an amount equal to the net periodic benefit cost. The expected benefit payments to participants in the Company's pension and other postretirement benefit plans for 2017 through 2021 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Other Pension Postretirement 2017 $ 219 $ 56 2018 226 57 2019 224 57 2020 221 60 2021 214 57 2022-2026 1,002 259 Plan Assets Investment Policy and Asset Allocations The Company's investment policy for its pension and other postretirement benefit plans is to balance risk and return through a diversified portfolio of debt securities, equity securities and other alternative investments. Maturities for debt securities are managed to targets consistent with prudent risk tolerances. The plans retain outside investment advisors to manage plan investments within the parameters outlined by each plan's Pension and Employee Benefits Plans Administrative Committee. The investment portfolio is managed in line with the investment policy with sufficient liquidity to meet near-term benefit payments. The target allocations (percentage of plan assets) for the Company's pension and other postretirement benefit plan assets are as follows as of December 31, 2016 : Other Pension Postretirement % % PacifiCorp: Debt securities (1) 33-37 33-37 Equity securities (1) 53-57 61-65 Limited partnership interests 8-12 1-3 Other 0-1 0-1 MidAmerican Energy: Debt securities (1) 20-40 25-45 Equity securities (1) 60-80 50-80 Real estate funds 2-8 — Other 0-5 0-5 NV Energy: Debt securities (1) 53-77 40 Equity securities (1) 23-47 60 (1) For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities. Fair Value Measurements The Company adopted ASU No. 2015-07, "Fair Value Measurement (Topic 820) - Disclosures for Investments in Certain Entities that Calculate Net Asset Value per Share (or its Equivalent)" effective January 1, 2016 under a retrospective method. The following table presents the fair value of plan assets, by major category, for the Company's defined benefit pension plans (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 4 $ 54 $ — $ 58 Debt securities: United States government obligations 161 — — 161 International government obligations — 2 — 2 Corporate obligations — 295 — 295 Municipal obligations — 20 — 20 Agency, asset and mortgage-backed obligations — 112 — 112 Equity securities: United States companies 583 — — 583 International companies 117 — — 117 Investment funds (2) 146 — — 146 Total assets in the fair value hierarchy $ 1,011 $ 483 $ — 1,494 Investment funds (2) measured at net asset value 920 Limited partnership interests (3) measured at net asset value 61 Real estate funds measured at net asset value 50 Total assets measured at fair value $ 2,525 As of December 31, 2015: Cash equivalents $ — $ 26 $ — $ 26 Debt securities: United States government obligations 155 — — 155 International government obligations — 4 — 4 Corporate obligations — 335 — 335 Municipal obligations — 25 — 25 Agency, asset and mortgage-backed obligations — 154 — 154 Equity securities: United States companies 586 — — 586 International companies 122 — — 122 Investment funds (2) 144 — — 144 Total assets in the fair value hierarchy $ 1,007 $ 544 $ — 1,551 Investment funds (2) measured at net asset value 823 Limited partnership interests (3) measured at net asset value 65 Real estate funds measured at net asset value 50 Total assets measured at fair value $ 2,489 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 62% and 38% , respectively, for 2016 and 66% and 34% , respectively, for 2015 . Additionally, these funds are invested in United States and international securities of approximately 60% and 40% , respectively, for 2016 and 58% and 42% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. The following table presents the fair value of plan assets, by major category, for the Company's defined benefit other postretirement plans (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 18 $ 2 $ — $ 20 Debt securities: United States government obligations 19 — — 19 Corporate obligations — 29 — 29 Municipal obligations — 39 — 39 Agency, asset and mortgage-backed obligations — 25 — 25 Equity securities: United States companies 217 — — 217 International companies 5 — — 5 Investment funds (2) 152 — — 152 Total assets in the fair value hierarchy $ 411 $ 95 $ — 506 Investment funds (2) measured at net asset value 156 Limited partnership interests (3) measured at net asset value 4 Total assets measured at fair value $ 666 As of December 31, 2015: Cash equivalents $ 12 $ 1 $ — $ 13 Debt securities: United States government obligations 18 — — 18 Corporate obligations — 33 — 33 Municipal obligations — 41 — 41 Agency, asset and mortgage-backed obligations — 28 — 28 Equity securities: United States companies 216 — — 216 International companies 6 — — 6 Investment funds (2) 149 — — 149 Total assets in the fair value hierarchy $ 401 $ 103 $ — 504 Investment funds (2) measured at net asset value 154 Limited partnership interests (3) measured at net asset value 4 Total assets measured at fair value $ 662 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 63% and 37% , respectively, for both 2016 and 2015 . Additionally, these funds are invested in United States and international securities of approximately 72% and 28% , respectively, for 2016 and 70% and 30% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. For level 1 investments, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. For level 2 investments, the fair value is determined using pricing models based on observable market inputs. Shares of mutual funds not registered under the Securities Act of 1933, private equity limited partnership interests, common and commingled trust funds and investment entities are reported at fair value based on the net asset value per unit, which is used for expedience purposes. A fund’s net asset value is based on the fair value of the underlying assets held by the fund less its liabilities. Foreign Operations Certain wholly-owned subsidiaries of Northern Powergrid participate in the Northern Powergrid group of the United Kingdom industry-wide Electricity Supply Pension Scheme (the "UK Plan"), which provides pension and other related defined benefits, based on final pensionable pay, to the majority of the employees of Northern Powergrid . The UK Plan is closed to employees hired after July 23, 1997. Employees hired after that date are covered by a defined contribution plan sponsored by a wholly-owned subsidiary of Northern Powergrid . Net Periodic Benefit Cost For purposes of calculating the expected return on pension plan assets, a market-related value is used. The market-related value of plan assets is calculated by spreading the difference between expected and actual investment returns over a five-year period beginning after the first year in which they occur. Net periodic benefit cost for the UK Plan included the following components for the years ended December 31 (in millions): 2016 2015 2014 Service cost $ 20 $ 24 $ 24 Interest cost 72 79 95 Expected return on plan assets (110 ) (116 ) (124 ) Net amortization 44 62 51 Net periodic benefit cost $ 26 $ 49 $ 46 Funded Status The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): 2016 2015 Plan assets at fair value, beginning of year $ 2,276 $ 2,368 Employer contributions 55 77 Participant contributions 1 2 Actual return on plan assets 349 48 Benefits paid (115 ) (91 ) Foreign currency exchange rate changes (397 ) (128 ) Plan assets at fair value, end of year $ 2,169 $ 2,276 The following table is a reconciliation of the benefit obligation for the years ended December 31 (in millions): 2016 2015 Benefit obligation, beginning of year $ 2,142 $ 2,279 Service cost 20 24 Interest cost 72 79 Participant contributions 1 2 Actuarial loss (gain) 387 (30 ) Benefits paid (115 ) (91 ) Foreign currency exchange rate changes (382 ) (121 ) Benefit obligation, end of year $ 2,125 $ 2,142 Accumulated benefit obligation, end of year $ 1,858 $ 1,891 The funded status of the UK Plan and the amounts recognized on the Consolidated Balance Sheets as of December 31 are as follows (in millions): 2016 2015 Plan assets at fair value, end of year $ 2,169 $ 2,276 Benefit obligation, end of year 2,125 2,142 Funded status $ 44 $ 134 Amounts recognized on the Consolidated Balance Sheets: Other assets $ 44 $ 134 Unrecognized Amounts The portion of the funded status of the UK Plan not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions): 2016 2015 Net loss $ 590 $ 592 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost, which are included in accumulated other comprehensive loss on the Consolidated Balance Sheets, for the years ended December 31 is as follows (in millions): 2016 2015 Balance, beginning of year $ 592 $ 655 Net loss arising during the year 148 38 Net amortization (44 ) (62 ) Foreign currency exchange rate changes (106 ) (39 ) Total (2 ) (63 ) Balance, end of year $ 590 $ 592 The net loss that will be amortized from accumulated other comprehensive loss in 2017 into net periodic benefit cost is estimated to be $65 million . Plan Assumptions Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: 2016 2015 2014 Benefit obligations as of December 31: Discount rate 2.70 % 3.70 % 3.60 % Rate of compensation increase 3.00 % 2.90 % 2.80 % Rate of future price inflation 3.00 % 2.90 % 2.80 % Net periodic benefit cost for the years ended December 31: Discount rate 3.70 % 3.60 % 4.40 % Expected return on plan assets 5.60 % 5.60 % 6.10 % Rate of compensation increase 2.90 % 2.80 % 3.15 % Rate of future price inflation 2.90 % 2.80 % 3.15 % Contributions and Benefit Payments Employer contributions to the UK Plan are expected to be £37 million during 2017 . The expected benefit payments to participants in the UK Plan for 2017 through 2021 and for the five years thereafter, using the foreign currency exchange rate as of December 31, 2016 , are summarized below (in millions): 2017 $ 75 2018 77 2019 79 2020 81 2021 83 2022-2026 448 Plan Assets Investment Policy and Asset Allocations The investment policy for the UK Plan is to balance risk and return through a diversified portfolio of debt securities, equity securities and real estate. Maturities for debt securities are managed to targets consistent with prudent risk tolerances. The UK Plan retains outside investment advisors to manage plan investments within the parameters set by the trustees of the UK Plan in consultation with Northern Powergrid . The investment portfolio is managed in line with the investment policy with sufficient liquidity to meet near-term benefit payments. The return on assets assumption is based on a weighted-average of the expected historical performance for the types of assets in which the UK Plan invests. The target allocations (percentage of plan assets) for the UK Plan assets are as follows as of December 31, 2016 : % Debt securities (1) 50-55 Equity securities (1) 35-40 Real estate funds and other 5-15 (1) For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds have been allocated based on the underlying investments in debt and equity securities. Fair Value Measurements The Company adopted ASU No. 2015-07, "Fair Value Measurement (Topic 820) - Disclosures for Investments in Certain Entities that Calculate Net Asset Value per Share (or its Equivalent)" effective January 1, 2016 under a retrospective method. The following table presents the fair value of the UK Plan assets, by major category, (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 4 $ 83 $ — $ 87 Debt securities: United Kingdom government obligations 718 — — 718 Equity securities: Investment funds (2) — 1,095 — 1,095 Real estate funds — — 105 105 Total $ 722 $ 1,178 $ 105 2,005 Investment funds (2) measured at net asset value 164 Total assets measured at fair value $ 2,169 As of December 31, 2015: Cash equivalents $ 46 $ — $ — $ 46 Debt securities: United Kingdom government obligations 424 — — 424 Other international government obligations — 13 — 13 Corporate obligations — 186 — 186 Equity securities: Investment funds (2) 24 1,189 — 1,213 Real estate funds — — 204 204 Total $ 494 $ 1,388 $ 204 2,086 Investment funds (2) measured at net asset value 190 Total assets measured at fair value $ 2,276 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 44% and 56% , respectively, for both 2016 and 2015 . The fair value of the UK Plan's assets are determined similar to the plan assets of the domestic plans as previously discussed. The following table reconciles the beginning and ending balances of the UK Plan assets measured at fair value using significant Level 3 inputs for the years ended December 31 (in millions): Real Estate Funds 2016 2015 2014 Beginning balance $ 204 $ 199 $ 179 Actual return on plan assets still held at period end 10 18 33 Sales (80 ) — — Foreign currency exchange rate changes (29 ) (13 ) (13 ) Ending balance $ 105 $ 204 $ 199 Defined Contribution Plans The Company sponsors various defined contribution plans covering substantially all employees. The Company's contributions vary depending on the plan, but matching contributions are based on each participant's level of contribution, and certain participants receive contributions based on eligible pre-tax annual compensation. Contributions cannot exceed the maximum allowable for tax purposes. The Company's contributions to these plans were $102 million , $90 million and $83 million for the years ended December 31, 2016 , 2015 and 2014 , respectively.
Nevada Power Company [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employee Benefit Plans [Text Block]	Retirement Plan and Postretirement Benefits Nevada Power is a participant in benefit plans sponsored by NV Energy . The NV Energy Retirement Plan includes a qualified pension plan ("Qualified Pension Plan") and a supplemental executive retirement plan and a restoration plan (collectively, "Non‑Qualified Pension Plans") that provide pension benefits for eligible employees. The NV Energy Comprehensive Welfare Benefit and Cafeteria Plan provides certain postretirement health care and life insurance benefits for eligible retirees ("Other Postretirement Plans") on behalf of Nevada Power . Nevada Power contributed $36 million , $- million and $- million to the Qualified Pension Plan for the year ended December 31 , 2016, 2015 and 2014, respectively. Nevada Power did not make any contributions to the Non‑Qualified Pension Plans or Other Postretirement Plans for the years ended December 31 , 2016, 2015 and 2014. Amounts attributable to Nevada Power were allocated from NV Energy based upon the current, or in the case of retirees, previous, employment location. Offsetting regulatory assets and liabilities have been recorded related to the amounts not yet recognized as a component of net periodic benefit costs that will be included in regulated rates. Net periodic benefit costs not included in regulated rates are included in accumulated other comprehensive loss, net. Amounts receivable from (payable to) NV Energy are included on the Consolidated Balance Sheets and consist of the following as of December 31 (in millions): 2016 2015 Qualified Pension Plan - Other long-term liabilities $ (24 ) $ (38 ) Non-Qualified Pension Plans: Other current liabilities (1 ) (1 ) Other long-term liabilities (9 ) (9 ) Other Postretirement Plans - Other long-term liabilities (4 ) (5 )
Sierra Pacific Power Company [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employee Benefit Plans [Text Block]	Retirement Plan and Postretirement Benefits Sierra Pacific is a participant in benefit plans sponsored by NV Energy . The NV Energy Retirement Plan includes a qualified pension plan ("Qualified Pension Plan") and a supplemental executive retirement plan and a restoration plan (collectively, "Non‑Qualified Pension Plans") that provide pension benefits for eligible employees. The NV Energy Comprehensive Welfare Benefit and Cafeteria Plan provides certain postretirement health care and life insurance benefits for eligible retirees ("Other Postretirement Plans") on behalf of Sierra Pacific . Sierra Pacific contributed $27 million , $- million and $- million to the Qualified Pension Plan for the year ended December 31 , 2016, 2015 and 2014, respectively. For the Other Postretirement Plans, Sierra Pacific contributed $1 million , $- million and $- million for the year ended December 31 , 2016, 2015 and 2014, respectively. Sierra Pacific did not make any contributions to the Non-Qualified Pension Plans for the years ended December 31 , 2016 , 2015 and 2014 . Amounts attributable to Sierra Pacific were allocated from NV Energy based upon the current, or in the case of retirees, previous, employment location. Offsetting regulatory assets and liabilities have been recorded related to the amounts not yet recognized as a component of net periodic benefit costs that will be included in regulated rates. Net periodic benefit costs not included in regulated rates are included in accumulated other comprehensive loss, net. Amounts payable to NV Energy are included on the Consolidated Balance Sheets and consist of the following as of December 31 (in millions): 2016 2015 Qualified Pension Plan - Other long-term liabilities $ (12 ) $ (29 ) Non-Qualified Pension Plans: Other current liabilities (1 ) (1 ) Other long-term liabilities (9 ) (9 ) Other Postretirement Plans - Other long-term liabilities (28 ) (32 )

Asset Retirement Obligations (N

Asset Retirement Obligations (Notes)	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations [Text Block]	Asset Retirement Obligations The Company estimates its ARO liabilities based upon detailed engineering calculations of the amount and timing of the future cash spending for a third party to perform the required work. Spending estimates are escalated for inflation and then discounted at a credit-adjusted, risk-free rate. Changes in estimates could occur for a number of reasons, including changes in laws and regulations, plan revisions, inflation and changes in the amount and timing of the expected work. The Company does not recognize liabilities for AROs for which the fair value cannot be reasonably estimated. Due to the indeterminate removal date, the fair value of the associated liabilities on certain generation, transmission, distribution and other assets cannot currently be estimated, and no amounts are recognized on the Consolidated Financial Statements other than those included in the cost of removal regulatory liability established via approved depreciation rates in accordance with accepted regulatory practices. These accruals totaled $2.2 billion as of December 31, 2016 and 2015 , respectively. The following table presents the Company's ARO liabilities by asset type as of December 31 (in millions): 2016 2015 Fossil fuel facilities $ 404 $ 443 Quad Cities Station 343 289 Wind generating facilities 124 104 Offshore pipeline facilities 33 31 Solar generating facilities 12 12 Other 38 42 Total asset retirement obligations $ 954 $ 921 Quad Cities Station nuclear decommissioning trust funds $ 460 $ 429 The following table reconciles the beginning and ending balances of the Company's ARO liabilities for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 921 $ 753 Change in estimated costs 33 104 Additions 25 59 Retirements (63 ) (32 ) Accretion 38 37 Ending balance $ 954 $ 921 Reflected as: Other current liabilities $ 98 $ 92 Other long-term liabilities 856 829 Total ARO liability $ 954 $ 921 The Nuclear Regulatory Commission regulates the decommissioning of nuclear power plants, which includes the planning and funding for the decommissioning. In accordance with these regulations, MidAmerican Energy submits a biennial report to the Nuclear Regulatory Commission providing reasonable assurance that funds will be available to pay for its share of the Quad Cities Station decommissioning. Certain of the Company's decommissioning and reclamation obligations relate to jointly owned facilities and mine sites, and as such, each subsidiary is committed to pay a proportionate share of the decommissioning or reclamation costs. In the event of a default by any of the other joint participants, the respective subsidiary may be obligated to absorb, directly or by paying additional sums to the entity, a proportionate share of the defaulting party's liability. The Company's estimated share of the decommissioning and reclamation obligations are primarily recorded as ARO liabilities. The 2016 change in estimated costs was primarily the result of a new decommissioning study conducted by the operator of the Quad Cities Station that changed the estimated amount and timing of cash flows. The 2015 change in estimated costs was primarily due to changes in the expected timing and amount of cash flows related to the implementation of the United States Environmental Protection Agency's final rule regulating the management and disposal of coal combustion byproducts resulting from the operation of coal-fueled generating facilities, including requirements for the operation and closure of surface impoundment and ash landfill facilities, which was effective in October 2015. In addition to substantially impacting existing AROs, the final rule also resulted in the recognition of additional AROs.
PacifiCorp [Member]
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations [Text Block]	Asset Retirement Obligations PacifiCorp estimates its ARO liabilities based upon detailed engineering calculations of the amount and timing of the future cash spending for a third party to perform the required work. Spending estimates are escalated for inflation and then discounted at a credit-adjusted, risk-free rate. Changes in estimates could occur for a number of reasons, including changes in laws and regulations, plan revisions, inflation and changes in the amount and timing of the expected work. PacifiCorp does not recognize liabilities for AROs for which the fair value cannot be reasonably estimated. Due to the indeterminate removal date, the fair value of the associated liabilities on certain transmission, distribution and other assets cannot currently be estimated, and no amounts are recognized on the Consolidated Financial Statements other than those included in the cost of removal regulatory liability established via approved depreciation rates in accordance with accepted regulatory practices. Cost of removal regulatory liabilities totaled $917 million and $894 million as of December 31, 2016 and 2015 , respectively. The following table reconciles the beginning and ending balances of PacifiCorp's ARO liabilities for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 224 $ 135 Change in estimated costs 2 62 Additions — 30 Retirements (19 ) (10 ) Accretion 8 7 Ending balance $ 215 $ 224 Reflected as: Other current liabilities $ 21 $ 35 Other long-term liabilities 194 189 $ 215 $ 224 Certain of PacifiCorp's decommissioning and reclamation obligations relate to jointly owned facilities and mine sites. PacifiCorp is committed to pay a proportionate share of the decommissioning or reclamation costs. In the event of a default by any of the other joint participants, PacifiCorp may be obligated to absorb, directly or by paying additional sums to the entity, a proportionate share of the defaulting party's liability. PacifiCorp's estimated share of the decommissioning and reclamation obligations are primarily recorded as ARO liabilities. In December 2014, the United States Environmental Protection Agency released its final rule regulating the management and disposal of coal combustion byproducts resulting from the operation of coal-fueled generating facilities, including requirements for the operation and closure of surface impoundment and ash landfill facilities. The final rule was published in the Federal Register in April 2015 and was effective in October 2015. The final rule substantially impacted existing AROs reflected in the December 31, 2015 change in estimated costs above and also resulted in the recognition of additional AROs.
MidAmerican Energy Company [Member]
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations [Text Block]	Asset Retirement Obligations MidAmerican Energy estimates its ARO liabilities based upon detailed engineering calculations of the amount and timing of the future cash spending for a third party to perform the required work. Spending estimates are escalated for inflation and then discounted at a credit-adjusted, risk-free rate. Changes in estimates could occur for a number of reasons, including changes in laws and regulations, plan revisions, inflation and changes in the amount and timing of the expected work. MidAmerican Energy does not recognize liabilities for AROs for which the fair value cannot be reasonably estimated. Due to the indeterminate removal date, the fair value of the associated liabilities on certain generation, transmission, distribution and other assets cannot currently be estimated, and no amounts are recognized on the Financial Statements other than those included in the cost of removal regulatory liability established via approved depreciation rates in accordance with accepted regulatory practices. These accruals totaled $665 million and $653 million as of December 31, 2016 and 2015 , respectively. The following table presents MidAmerican Energy's ARO liabilities by asset type as of December 31, (in millions): 2016 2015 Quad Cities Station $ 343 $ 289 Fossil-fueled generating facilities 132 160 Wind-powered generating facilities 91 82 Other 1 1 Total asset retirement obligations $ 567 $ 532 Quad Cities Station nuclear decommissioning trust funds (1) $ 460 $ 429 (1) Refer to Note 7 for a discussion of the Quad Cities Station nuclear decommissioning trust funds. The following table reconciles the beginning and ending balances of MidAmerican Energy's ARO liabilities for the years ended December 31, (in millions): 2016 2015 Beginning balance $ 532 $ 460 Change in estimated costs 28 36 Additions 14 22 Retirements (32 ) (9 ) Accretion 25 23 Ending balance $ 567 $ 532 Reflected as: Other current liabilities $ 57 $ 44 Asset retirement obligations 510 488 $ 567 $ 532 The change in estimated costs for 2016 was primarily the result of a new decommissioning study conducted by the operator of Quad Cities Station that changed the estimated amount and timing of cash flows. The change in estimated costs for 2015 was primarily due to changes in the expected timing and amount of cash flows related to the implementation of the United States Environmental Protection Agency's final rule regulating the management and disposal of coal combustion byproducts resulting from the operation of coal-fueled generating facilities, including requirements for the operation and closure of surface impoundment and ash landfill facilities, which was effective in October 2015.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations [Text Block]	Asset Retirement Obligations Refer to Note 12 of MidAmerican Energy's Notes to Financial Statements.
Nevada Power Company [Member]
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations [Text Block]	Asset Retirement Obligations Nevada Power estimates its ARO liabilities based upon detailed engineering calculations of the amount and timing of the future cash spending for a third party to perform the required work. Spending estimates are escalated for inflation and then discounted at a credit-adjusted, risk-free rate. Changes in estimates could occur for a number of reasons, including changes in laws and regulations, plan revisions, inflation and changes in the amount and timing of the expected work. Nevada Power does not recognize liabilities for AROs for which the fair value cannot be reasonably estimated. Due to the indeterminate removal date, the fair value of the associated liabilities on certain generation, transmission, distribution and other assets cannot currently be estimated, and no amounts are recognized on the Consolidated Financial Statements other than those included in the cost of removal regulatory liability established via approved depreciation rates in accordance with accepted regulatory practices. These accruals totaled $294 million and $273 million as of December 31 , 2016 and 2015 , respectively. The following table presents Nevada Power 's ARO liabilities by asset type as of December 31 (in millions): 2016 2015 Waste water remediation $ 38 $ 42 Evaporative ponds and dry ash landfills 22 27 Asbestos 4 3 Solar 2 2 Other 17 11 Total asset retirement obligations $ 83 $ 85 The following table reconciles the beginning and ending balances of Nevada Power 's ARO liabilities for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 85 $ 86 Change in estimated costs 4 3 Additions — 3 Retirements (10 ) (11 ) Accretion 4 4 Ending balance $ 83 $ 85 Reflected as: Other current liabilities $ 20 $ 13 Other long-term liabilities 63 72 $ 83 $ 85 In 2008, Nevada Power signed an administrative order of consent as owner and operator of Reid Gardner Generating Station Unit Nos. 1, 2 and 3 and as co-owner and operating agent of Unit No. 4. Based on the administrative order of consent, Nevada Power recorded estimated AROs and capital remediation costs. However, actual costs of work under the administrative order of consent may vary significantly once the scope of work is defined and additional site characterization has been completed. In connection with the termination of the co-ownership arrangement, effective October 22, 2013, between Nevada Power and California Department of Water Resources ("CDWR") for the Reid Gardner Generating Station Unit No. 4, Nevada Power and CDWR entered into a cost-sharing agreement that sets forth how the parties will jointly share in costs associated with all investigation, characterization and, if necessary, remedial activities as required under the administrative order of consent. Certain of Nevada Power 's decommissioning and reclamation obligations relate to jointly-owned facilities, and as such, Nevada Power is committed to pay a proportionate share of the decommissioning or reclamation costs. In the event of a default by any of the other joint participants, the respective subsidiary may be obligated to absorb, directly or by paying additional sums to the entity, a proportionate share of the defaulting party's liability. Management has identified legal obligations to retire generation plant assets specified in land leases for Nevada Power 's jointly-owned Navajo Generating Station and the Higgins Generating Station. Provisions of the lease require the lessees to remove the facilities upon request of the lessors at the expiration of the leases. Nevada Power 's estimated share of the decommissioning and reclamation obligations are primarily recorded as ARO liabilities in other long-term liabilities on the Consolidated Balance Sheets. The 2015 change in estimated costs is primarily due to changes in the amount and timing of cash flows related to the implementation of the United States Environmental Protection Agency's (" EPA ") final rule regulating the management and disposal of coal combustion byproducts resulting from the operation of coal-fueled generating facilities, including requirements for the operation and closure of surface impoundment and ash landfill facilities. The final rule was published in the Federal Register in April 2015 and was effective in October 2015. In addition to impacting existing AROs, the final rule also resulted in the recognition of additional AROs.
Sierra Pacific Power Company [Member]
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations [Text Block]	Asset Retirement Obligations Sierra Pacific estimates its ARO liabilities based upon detailed engineering calculations of the amount and timing of the future cash spending for a third party to perform the required work. Spending estimates are escalated for inflation and then discounted at a credit-adjusted, risk-free rate. Changes in estimates could occur for a number of reasons, including changes in laws and regulations, plan revisions, inflation and changes in the amount and timing of the expected work. Sierra Pacific does not recognize liabilities for AROs for which the fair value cannot be reasonably estimated. Due to the indeterminate removal date, the fair value of the associated liabilities on certain generation, transmission, distribution and other assets cannot currently be estimated, and no amounts are recognized on the Consolidated Financial Statements other than those included in the cost of removal regulatory liability established via approved depreciation rates in accordance with accepted regulatory practices. These accruals totaled $205 million and $208 million as of December 31 , 2016 and 2015 , respectively. The following table presents Sierra Pacific 's ARO liabilities by asset type as of December 31 (in millions): 2016 2015 Asbestos $ 4 $ 4 Evaporative ponds and dry ash landfills 3 3 Other 3 3 Total asset retirement obligations $ 10 $ 10 The following table reconciles the beginning and ending balances of Sierra Pacific 's ARO liabilities for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 10 $ 11 Retirements — (1 ) Ending balance $ 10 $ 10 Reflected as: Other current liabilities $ — $ — Other long-term liabilities 10 10 $ 10 $ 10 Certain of Sierra Pacific 's decommissioning and reclamation obligations relate to jointly-owned facilities, and as such, Sierra Pacific is committed to pay a proportionate share of the decommissioning or reclamation costs. In the event of a default by any of the other joint participants, the respective subsidiary may be obligated to absorb, directly or by paying additional sums to the entity, a proportionate share of the defaulting party's liability. Sierra Pacific 's estimated share of the decommissioning and reclamation obligations are primarily recorded as ARO liabilities in other long-term liabilities on the Consolidated Balance Sheets. In December 2014, the United States Environmental Protection Agency (" EPA ") released its final rule regulating the management and disposal of coal combustion byproducts resulting from the operation of coal-fueled generating facilities, including requirements for the operation and closure of surface impoundment and ash landfill facilities. The final rule was published in the Federal Register in April 2015 and was effective in October 2015. The effects of the new rule did not have a material impact on Sierra Pacific 's ARO balance.

Commitments and Contingencies (

Commitments and Contingencies (Notes)	12 Months Ended
	Dec. 31, 2016
Contractual Obligation [Line Items]
Commitments and Contingencies	Commitments and Contingencies Commitments The Company has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31, 2016 are as follows (in millions): 2022 and 2017 2018 2019 2020 2021 Thereafter Total Contract type: Fuel, capacity and transmission contract commitments $ 2,370 $ 1,606 $ 1,389 $ 1,208 $ 1,010 $ 10,053 $ 17,636 Construction commitments 852 49 66 1 1 4 973 Operating leases and easements 141 122 101 87 73 1,085 1,609 Maintenance, service and other contracts 303 220 212 186 180 723 1,824 $ 3,666 $ 1,997 $ 1,768 $ 1,482 $ 1,264 $ 11,865 $ 22,042 Fuel, Capacity and Transmission Contract Commitments The Utilities have fuel supply and related transportation and lime contracts for their coal- and natural gas-fueled generating facilities. The Utilities expect to supplement these contracts with additional contracts and spot market purchases to fulfill their future fossil fuel needs. The Utilities acquire a portion of their electricity through long-term purchases and exchange agreements. The Utilities have several power purchase agreements with wind-powered generating facilities that are not included in the table above as the payments are based on the amount of energy generated and there are no minimum payments. The Utilities also have contracts for the right to transmit electricity over other entities' transmission lines to facilitate delivery to their customers. MidAmerican Energy has long-term rail transportation contracts with BNSF Railway Company ("BNSF"), an affiliate company, and Union Pacific Railroad Company for the transportation of coal to all of the MidAmerican Energy-operated coal-fueled generating facilities. For the years ended December 31, 2016 , 2015 and 2014 , $137 million , $185 million and $159 million , respectively, were incurred for coal transportation services, the majority of which was related to the BNSF agreement. Construction Commitments The Company's firm construction commitments reflected in the table above include the following major construction projects: • MidAmerican Energy's construction of wind-powered generating facilities in 2017 and two Multi-Value Projects approved by the Midcontinent Independent System Operator, Inc. for high voltage transmission lines in Iowa and Illinois in 2017. • ALP's investments in directly assigned transmission projects from the AESO . • PacifiCorp's costs associated with investments in emissions control equipment and certain transmission and distribution projects. Operating Leases and Easements The Company has non-cancelable operating leases primarily for office equipment, office space, certain operating facilities, land and rail cars. These leases generally require the Company to pay for insurance, taxes and maintenance applicable to the leased property. Certain leases contain renewal options for varying periods and escalation clauses for adjusting rent to reflect changes in price indices. The Company also has non-cancelable easements for land on which its wind-powered generating facilities are located. Rent expense on non-cancelable operating leases totaled $156 million for 2016 , $161 million for 2015 and $146 million for 2014 . Maintenance, Service and Other Contracts The Company has entered into service agreements related to its nonregulated solar and wind-powered projects with third parties to operate and maintain the projects under fixed-fee operating and maintenance agreements. Additionally, t he Company has various non-cancelable maintenance, service and other contracts primarily related to turbine and equipment maintenance and various other service agreements. Legal Matters The Company is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. The Company does not believe that such normal and routine litigation will have a material impact on its consolidated financial results. Environmental Laws and Regulations The Company is subject to federal, state, local and foreign laws and regulations regarding air and water quality, renewable portfolio standards, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact its current and future operations. The Company believes it is in material compliance with all applicable laws and regulations. Hydroelectric Relicensing PacifiCorp's Klamath hydroelectric system is currently operating under annual licenses with the FERC. In February 2010, PacifiCorp, the United States Department of the Interior, the United States Department of Commerce, the state of California, the state of Oregon and various other governmental and non-governmental settlement parties signed the Klamath Hydroelectric Settlement Agreement ("KHSA"). Among other things, the KHSA provided that the United States Department of the Interior would conduct scientific and engineering studies to assess whether removal of the Klamath hydroelectric system's mainstem dams was in the public interest and would advance restoration of the Klamath Basin's salmonid fisheries. If it was determined that dam removal should proceed, dam removal would begin no earlier than 2020. Congress failed to pass legislation needed to implement the original KHSA. In February 2016, the principal parties to the KHSA (PacifiCorp, the states of California and Oregon and the United States Departments of the Interior and Commerce) executed an agreement in principle committing to explore potential amendment of the KHSA to facilitate removal of the Klamath dams through a FERC process without the need for federal legislation. On April 6, 2016, PacifiCorp, the states of California and Oregon, and the United States Departments of the Interior and Commerce and other stakeholders executed an amendment to the KHSA. Consistent with the terms of the amended KHSA, on September 23, 2016, PacifiCorp and the Klamath River Renewal Corporation ("KRRC")" jointly filed an application with the FERC to transfer the license for the four mainstem Klamath River hydroelectric generating facilities from PacifiCorp to the KRRC. Also on September 23, 2016, the KRRC filed an application with the FERC to surrender the license and decommission the facilities. The KRRC's license surrender application included a request for the FERC to refrain from acting on the surrender application until after the transfer of the license to the KRRC is effective. Under the amended KHSA, PacifiCorp and its customers continue to be protected from uncapped dam removal costs and liabilities. The KRRC must indemnify PacifiCorp from liabilities associated with dam removal. The amended KHSA also limits PacifiCorp's contribution to facilities removal costs to no more than $200 million , of which up to $184 million would be collected from PacifiCorp's Oregon customers with the remainder to be collected from PacifiCorp's California customers. California voters approved a water bond measure in November 2014 from which the state of California's contribution towards facilities removal costs will be drawn. In accordance with this bond measure, additional funding of up to $250 million for facilities removal costs was included in the California state budget in 2016, with the funding effective for at least five years. If facilities removal costs exceed the combined funding that will be available from PacifiCorp's Oregon and California customers and the state of California, sufficient funds would need to be provided by the KRRC or an entity other than PacifiCorp in order for removal to proceed. If certain conditions in the amended KHSA are not satisfied and the license does not transfer to the KRRC, PacifiCorp will resume relicensing with the FERC. As of December 31, 2016 , PacifiCorp's assets included $68 million of costs associated with the Klamath hydroelectric system's mainstem dams and the associated relicensing and settlement costs, which are being depreciated and amortized in accordance with state regulatory approvals through either December 31, 2019, or December 31, 2022, depending upon the state jurisdiction. Hydroelectric Commitments Certain of PacifiCorp's hydroelectric licenses contain requirements for PacifiCorp to make certain capital and operating expenditures related to its hydroelectric facilities. PacifiCorp estimates it is obligated to make capital expenditures of approximately $227 million over the next 10 years related to these licenses. Guarantees The Company has entered into guarantees as part of the normal course of business and the sale of certain assets. These guarantees are not expected to have a material impact on the Company's consolidated financial results.
PacifiCorp [Member]
Contractual Obligation [Line Items]
Commitments and Contingencies	Commitments and Contingencies Legal Matters PacifiCorp is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. PacifiCorp does not believe that such normal and routine litigation will have a material impact on its consolidated financial results. Environmental Laws and Regulations PacifiCorp is subject to federal, state and local laws and regulations regarding air and water quality, renewable portfolio standards, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact PacifiCorp's current and future operations. PacifiCorp believes it is in material compliance with all applicable laws and regulations. Hydroelectric Relicensing PacifiCorp's Klamath hydroelectric system is currently operating under annual licenses with the FERC. In February 2010, PacifiCorp, the United States Department of the Interior, the United States Department of Commerce, the state of California, the state of Oregon and various other governmental and non-governmental settlement parties signed the Klamath Hydroelectric Settlement Agreement ("KHSA"). Among other things, the KHSA provided that the United States Department of the Interior would conduct scientific and engineering studies to assess whether removal of the Klamath hydroelectric system's mainstem dams was in the public interest and would advance restoration of the Klamath Basin's salmonid fisheries. If it was determined that dam removal should proceed, dam removal would begin no earlier than 2020. Congress failed to pass legislation needed to implement the original KHSA. Hence, in February 2016, the principal parties to the KHSA (PacifiCorp, the states of California and Oregon and the United States Departments of the Interior and Commerce) executed an agreement in principle committing to explore potential amendment of the KHSA to facilitate removal of the Klamath dams through a FERC process without the need for federal legislation. On April 6, 2016, PacifiCorp, the states of California and Oregon, and the United States Departments of the Interior and Commerce and other stakeholders executed an amendment to the KHSA. Consistent with the terms of the amended KHSA, on September 23, 2016, PacifiCorp and the Klamath River Renewal Corporation ("KRRC") jointly filed an application with the FERC to transfer the license for the four mainstem Klamath River hydroelectric generating facilities from PacifiCorp to the KRRC. Also on September 23, 2016, the KRRC filed an application with the FERC to surrender the license and decommission the facilities. The KRRC's license surrender application included a request for the FERC to refrain from acting on the surrender application until after the transfer of the license to the KRRC is effective. Under the amended KHSA, PacifiCorp and its customers continue to be protected from uncapped dam removal costs and liabilities. The KRRC must indemnify PacifiCorp from liabilities associated with dam removal. The amended KHSA also limits PacifiCorp's contribution to facilities removal costs to no more than $200 million , of which up to $184 million would be collected from PacifiCorp's Oregon customers with the remainder to be collected from PacifiCorp's California customers. California voters approved a water bond measure in November 2014 from which the state of California's contribution towards facilities removal costs will be drawn. In accordance with this bond measure, additional funding of up to $250 million for facilities removal costs was included in the California state budget in 2016, with the funding effective for at least five years. If facilities removal costs exceed the combined funding that will be available from PacifiCorp's Oregon and California customers and the state of California, sufficient funds would need to be provided by the KRRC or an entity other than PacifiCorp in order for removal to proceed. If certain conditions in the amended KHSA are not satisfied and the license does not transfer to the KRRC, PacifiCorp will resume relicensing with the FERC. As of December 31, 2016 , PacifiCorp's assets included $68 million of costs associated with the Klamath hydroelectric system's mainstem dams and the associated relicensing and settlement costs, which are being depreciated and amortized in accordance with state regulatory approvals through either December 31, 2019, or December 31, 2022, depending upon the state jurisdiction. Hydroelectric Commitments Certain of PacifiCorp's hydroelectric licenses contain requirements for PacifiCorp to make certain capital and operating expenditures related to its hydroelectric facilities. PacifiCorp estimates it is obligated to make capital expenditures of approximately $227 million over the next 10 years related to these licenses. Commitments PacifiCorp has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31, 2016 are as follows (in millions): 2017 2018 2019 2020 2021 2022 and Thereafter Total Contract type: Purchased electricity contracts - commercially operable $ 253 $ 160 $ 157 $ 157 $ 145 $ 1,630 $ 2,502 Purchased electricity contracts - non-commercially operable 10 13 17 17 18 390 465 Fuel contracts 796 616 596 507 346 1,407 4,268 Construction commitments 62 46 26 4 1 4 143 Transmission 109 106 90 61 47 467 880 Operating leases and easements 5 5 5 5 4 39 63 Maintenance, service and other contracts 53 29 31 17 20 68 218 Total commitments $ 1,288 $ 975 $ 922 $ 768 $ 581 $ 4,005 $ 8,539 Purchased Electricity Contracts - Commercially Operable As part of its energy resource portfolio, PacifiCorp acquires a portion of its electricity through long-term purchases and exchange agreements. PacifiCorp has several power purchase agreements with wind-powered generating facilities that are not included in the table above as the payments are based on the amount of energy generated and there are no minimum payments. Included in the purchased electricity payments are any power purchase agreements that meet the definition of a lease. Rent expense related to those power purchase agreements that meet the definition of a lease totaled $14 million for 2016 , $13 million for 2015 and $15 million for 2014 . Included in the minimum fixed annual payments for purchased electricity above are commitments to purchase electricity from several hydroelectric systems under long-term arrangements with public utility districts. These purchases are made on a "cost-of-service" basis for a stated percentage of system output and for a like percentage of system operating expenses and debt service. These costs are included in energy costs on the Consolidated Statements of Operations. PacifiCorp is required to pay its portion of operating costs and its portion of the debt service, whether or not any electricity is produced. These arrangements accounted for less than 5% of PacifiCorp's 2016 , 2015 and 2014 energy sources. Purchased Electricity Contracts - Non-commercially Operable PacifiCorp has several contracts for purchases of electricity from facilities that have not yet achieved commercial operation. To the extent any of these facilities do not achieve commercial operation, PacifiCorp has no obligation to the counterparty. Fuel Contracts PacifiCorp has "take or pay" coal and natural gas contracts that require minimum payments. Construction Commitments PacifiCorp's construction commitments included in the table above relate to firm commitments and include costs associated with investments in emissions control equipment and certain transmission and distribution projects. Transmission PacifiCorp has contracts for the right to transmit electricity over other entities' transmission lines to facilitate delivery to PacifiCorp's customers. Operating Leases and Easements PacifiCorp has non-cancelable operating leases primarily for certain operating facilities, office space, land and equipment that expire at various dates through the year ending December 31, 2092. These leases generally require PacifiCorp to pay for insurance, taxes and maintenance applicable to the leased property. Certain leases contain renewal options for varying periods and escalation clauses for adjusting rent to reflect changes in price indices. PacifiCorp also has non-cancelable easements for land on which its wind-powered generating facilities are located. Rent expense totaled $15 million for the years ended December 31, 2016 and 2015 , and $16 million for 2014 . Guarantees PacifiCorp has entered into guarantees as part of the normal course of business and the sale of certain assets. These guarantees are not expected to have a material impact on PacifiCorp's consolidated financial results.
MidAmerican Energy Company [Member]
Contractual Obligation [Line Items]
Commitments and Contingencies	Commitments and Contingencies Commitments MidAmerican Energy had the following firm commitments that are not reflected on the Balance Sheet. Minimum payments as of December 31, 2016 , are as follows (in millions): 2022 and 2017 2018 2019 2020 2021 Thereafter Total Contract type: Coal and natural gas for generation $ 141 $ 73 $ 40 $ — $ — $ — $ 254 Electric capacity and transmission 37 29 29 28 25 59 207 Natural gas contracts for gas operations 137 34 13 12 10 23 229 Construction commitments 347 2 5 — — — 354 Easements and operating leases 20 20 20 19 19 624 722 Maintenance and services contracts 72 90 91 92 86 210 641 $ 754 $ 248 $ 198 $ 151 $ 140 $ 916 $ 2,407 Coal, Natural Gas, Electric Capacity and Transmission Commitments MidAmerican Energy has coal supply and related transportation and lime contracts for its coal-fueled generating facilities. MidAmerican Energy expects to supplement the coal contracts with additional contracts and spot market purchases to fulfill its future coal supply needs. Additionally, MidAmerican Energy has a natural gas transportation contract for a natural gas-fueled generating facility. The contracts have minimum payment commitments ranging through 2019 . MidAmerican Energy has various natural gas supply and transportation contracts for its regulated and nonregulated gas operations that have minimum payment commitments ranging through 2025 . MidAmerican Energy has contracts to purchase electric capacity to meet its electric system energy requirements that have minimum payment commitments ranging through 2028 . MidAmerican Energy also has contracts for the right to transmit electricity over other entities' transmission lines with minimum payment commitments ranging through 2022 . Construction Commitments MidAmerican Energy's firm construction commitments reflected in the table above consist primarily of contracts for the construction of wind-powered generating facilities in 2017, the settlement of asset retirement obligations for ash pond closures and the construction in 2017 of two Multi-Value Projects approved by the Midcontinent Independent System Operator, Inc. for high voltage transmission lines in Iowa and Illinois. Easements and Operating Leases MidAmerican Energy has non-cancelable easements with minimum payment commitments ranging through 2061 for land in Iowa on which its wind-powered generating facilities are located. MidAmerican Energy also has non-cancelable operating leases with minimum payment commitments ranging through 2020 primarily for office and other building space, rail cars and computer equipment. These leases generally require MidAmerican Energy to pay for insurance, taxes and maintenance applicable to the leased property. Certain leases contain renewal options for varying periods and escalation clauses for adjusting rent to reflect changes in price indices. Rent expense on non-cancelable operating leases totaled $4 million , $4 million and $4 million for 2016 , 2015 and 2014 , respectively. Maintenance and Services Contracts MidAmerican Energy has non-cancelable maintenance and services contracts related to various generating facilities with minimum payment commitments ranging through 2027 . Environmental Laws and Regulations MidAmerican Energy is subject to federal, state and local laws and regulations regarding air and water quality, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact its current and future operations. MidAmerican Energy believes it is in material compliance with all applicable laws and regulations. Transmission Rates MidAmerican Energy's wholesale transmission rates are set annually using FERC-approved formula rates subject to true-up for actual cost of service. Prior to September 2016, the rates in effect were based on a 12.38% return on equity ("ROE"). In November 2013 and February 2015, a coalition of intervenors filed successive complaints with the FERC requesting that the 12.38% ROE no longer be found just and reasonable and sought to reduce the base ROE to 9.15% and 8.67% , respectively. MidAmerican Energy is authorized by the FERC to include a 0.50% adder beyond the base ROE effective January 2015. In September 2016, the FERC issued an order for the first complaint, which reduces the base ROE to 10.32% and requires refunds, plus interest, for the period from November 2013 through February 2015. The FERC is expected to rule on the second complaint by the second quarter of 2017, covering the period from February 2015 through May 2016. MidAmerican Energy believes it is probable that the FERC will order a base ROE lower than 12.38% in the second complaint and, as of December 31, 2016, has accrued a $10 million liability for refunds under both complaints of amounts collected under the higher ROE from November 2013 through May 2016. Legal Matters MidAmerican Energy is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. MidAmerican Energy does not believe that such normal and routine litigation will have a material impact on its financial results.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Contractual Obligation [Line Items]
Commitments and Contingencies	Commitments and Contingencies Refer to Note 15 of MidAmerican Energy's Notes to Financial Statements. Legal Matters MidAmerican Funding is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. MidAmerican Funding does not believe that such normal and routine litigation will have a material impact on its consolidated financial results.
Nevada Power Company [Member]
Contractual Obligation [Line Items]
Commitments and Contingencies	Commitments and Contingencies Environmental Laws and Regulations Nevada Power is subject to federal, state and local laws and regulations regarding air and water quality, renewable portfolio standards, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact Nevada Power 's current and future operations. Nevada Power believes it is in material compliance with all applicable laws and regulations. Senate Bill 123 In June 2013, the Nevada State Legislature passed Senate Bill No. 123 ("SB 123"), which included the retirement of coal plants and replacing the capacity with renewable facilities and other generating facilities. In May 2014, Nevada Power filed its Emissions Reduction Capacity Replacement Plan ("ERCR Plan") in compliance with SB 123. In July 2015, Nevada Power filed an amendment to its ERCR Plan with the PUCN which was approved in September 2015. In June 2015, the Nevada State Legislature passed Assembly Bill No. 498, which modified the capacity replacement components of SB 123. Consistent with the Emissions Reduction and Capacity Replacement Plan ("ERCR Plan"), Nevada Power acquired a 272 -MW natural gas co-generating facility in 2014, acquired a 210 -MW natural gas peaking facility in 2014, constructed a 15 -MW solar photovoltaic facility in 2015 and contracted two renewable power purchase agreements with 100 -MW solar photovoltaic generating facilities in 2015. In February 2016, Nevada Power solicited proposals to acquire 35 MW of nameplate renewable energy capacity to be owned by Nevada Power. Nevada Power did not enter into any agreements to acquire the 35 MW of nameplate renewable energy capacity; however, it has the option to acquire the 35 MW in the future under the ERCR Plan, subject to PUCN approval. In addition, Nevada Power was granted approval to purchase the remaining 130 MW of the Silverhawk natural gas-fueled combined cycle generating facility. In June 2016, Nevada Power executed a long-term power purchase agreement for 100 MW of nameplate renewable energy capacity in Nevada. In December 2016, the order was approved. In addition the order approved the early retirement of Reid Gardner Unit 4 in the first quarter of 2017. These transactions are related to Nevada Power's compliance with Senate Bill No. 123, resulting in the retirement of 812 MW of coal-fueled generation by 2019. Reid Gardner Generation Station In October 2011, Nevada Power received a request for information from the EPA Region 9 under Section 114 of the Clean Air Act requesting current and historical operations and capital project information for Nevada Power 's Reid Gardner Generating Station located near Moapa, Nevada. The EPA 's Section 114 information request does not allege any incidents of non-compliance at the plant, and there have been no other new enforcement-related proceedings that have been initiated by the EPA relating to the plant. Nevada Power completed its responses to the EPA during the first quarter of 2012 and will continue to monitor developments relating to this Section 114 request. At this time, Nevada Power cannot predict the impact, if any, associated with this information request. Legal Matters Nevada Power is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. Nevada Power does not believe that such normal and routine litigation will have a material impact on its consolidated financial results. The Company is also involved in other kinds of legal actions, some of which assert or may assert claims or seek to impose fines, penalties and other costs in substantial amounts and are described below. Switch, Ltd. In July 2016, Switch filed a complaint in the United States District Court for the District of Nevada against various parties, including Nevada Power. In September 2016, Switch filed an amended complaint. The amended complaint alleges that actions by the former general counsel of the PUCN, as well as the PUCN and the PUCN Staff, violated state and federal laws and as a result of those actions Switch was prevented from being able to utilize an alternative energy provider. Switch also alleges that Nevada Power was aware of the wrong doing and either participated in the activities or failed to take action to stop the wrong doing, and as a result Nevada Power has been improperly enriched by these activities. In addition, Switch asserted antitrust claims against Nevada Power. Switch was seeking monetary damages and to invalidate the settlement agreement between Switch and Nevada Power relating to Switch utilizing an alternative energy provider. In December 2016, the PUCN issued an order resolving the matters in the complaint. The order approved a stipulation between Switch and the Operations Staff of the PUCN, which allows Switch to purchase energy from alternative providers of a new electric resource and become a distribution only service customer. In January 2017, Switch voluntarily dismissed the federal court case with prejudice. Commitments Nevada Power has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31 , 2016 are as follows (in millions): 2017 2018 2019 2020 2021 2022 and Thereafter Total Contract type: Fuel, capacity and transmission contract commitments $ 697 $ 445 $ 352 $ 355 $ 358 $ 5,310 $ 7,517 Fuel and capacity contract commitments (not commercially operable) 7 14 29 36 37 683 806 Operating leases and easements 9 9 8 7 7 51 91 Maintenance, service and other contracts 118 39 37 37 36 75 342 Total commitments $ 831 $ 507 $ 426 $ 435 $ 438 $ 6,119 $ 8,756 Fuel and Capacity Contract Commitments Purchased Power Nevada Power has several contracts for long-term purchase of electric energy which have been approved by the PUCN. The expiration of these contracts range from 2017 to 2067 . Purchased power includes contracts which meet the definition of a lease. Nevada Power 's operating and maintenance expense for purchase power contracts which met the lease criteria for 2016 , 2015 and 2014 were $302 million , $264 million and $245 million , respectively, and are recorded as cost of fuel, energy and capacity on the Consolidated Statements of Operations. Coal and Natural Gas Nevada Power has a contract for the transportation of coal that extends through 2017 . Additionally, gas transportation contracts expire from 2017 to 2032 and the gas supply contract expires in 2018 . Fuel and Capacity Contract Commitments - Not Commercially Operable Nevada Power has several contracts for long-term purchase of electric energy in which the facility remains under development. Amounts represent the estimated payments under renewable energy power purchase contracts, which have been approved by the PUCN and are contingent upon the developers obtaining commercial operation and their ability to deliver power. Operating Leases and Easements Nevada Power has non-cancelable operating leases primarily for office equipment, office space, certain operating facilities, vehicles and land. These leases generally require Nevada Power to pay for insurance, taxes and maintenance applicable to the leased property. Certain leases contain renewal options for varying periods and escalation clauses for adjusting rent to reflect changes in price indices. Nevada Power also has non-cancelable easements for land. Operating and maintenance expense on non-cancelable operating leases totaled $13 million , $11 million and $10 million for the years ended December 31 , 2016 , 2015 and 2014 , respectively. Maintenance, Service and Other Contracts Nevada Power has long-term service agreements for the performance of maintenance on generation units. Obligation amounts are based on estimated usage. The estimated expiration of these service agreements range from 2017 to 2026 .
Sierra Pacific Power Company [Member]
Contractual Obligation [Line Items]
Commitments and Contingencies	Commitments and Contingencies Environmental Laws and Regulations Sierra Pacific is subject to federal, state and local laws and regulations regarding air and water quality, renewable portfolio standards, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact Sierra Pacific 's current and future operations. Sierra Pacific believes it is in material compliance with all applicable laws and regulations. Valmy Generation Station In June 2009, Sierra Pacific received a request for information from the EPA Region 9 under Section 114 of the Clean Air Act requesting current and historical operations and capital project information for Sierra Pacific 's Valmy Generating Station located in Valmy, Nevada. Sierra Pacific co-owns and operates this coal-fueled generating facility. Idaho Power Company owns the remaining 50% . The EPA 's Section 114 information request does not allege any incidents of non-compliance at the plant, and there have been no other new enforcement-related proceedings that have been initiated by the EPA relating to the plant. Sierra Pacific completed its responses to the EPA in December 2009 and will continue to monitor developments relating to this Section 114 request. At this time, Sierra Pacific cannot predict the impact, if any, associated with this information request. Legal Matters Sierra Pacific is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. Sierra Pacific does not believe that such normal and routine litigation will have a material impact on its consolidated financial results. Commitments Sierra Pacific has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31 , 2016 are as follows (in millions): 2022 and 2017 2018 2019 2020 2021 Thereafter Total Contract type: Fuel, capacity and transmission contract commitments $ 238 $ 156 $ 103 $ 71 $ 62 $ 375 $ 1,005 Fuel and capacity contract commitments (not commercially operable) 5 10 10 11 11 215 262 Operating leases and easements 4 4 3 3 3 46 63 Maintenance, service and other contracts 4 5 4 6 6 17 42 Total commitments $ 251 $ 175 $ 120 $ 91 $ 82 $ 653 $ 1,372 Fuel and Capacity Contract Commitments Purchased Power Sierra Pacific has several contracts for long-term purchase of electric energy which have been approved by the PUCN. The expiration of these contracts range from 2017 to 2039 . Purchased power includes contracts which meet the definition of a lease. Sierra Pacific 's operating and maintenance expense for purchase power contracts which met the lease criteria for 2016 , 2015 and 2014 were $69 million , $65 million and $68 million , respectively, and are recorded as cost of fuel, energy and capacity on the Consolidated Statements of Operations. Coal and Natural Gas Sierra Pacific has several long-term contracts for the transport of coal that expire from 2017 to 2018 . Additionally, gas transportation contracts expire from 2018 to 2046 and the gas supply contracts expire from 2017 to 2018 . Operating Leases Sierra Pacific has non-cancelable operating leases primarily for office equipment, office space, certain operating facilities, vehicles and land. These leases generally require Sierra Pacific to pay for insurance, taxes and maintenance applicable to the leased property. Certain leases contain renewal options for varying periods and escalation clauses for adjusting rent to reflect changes in price indices. Sierra Pacific also has non-cancelable easements for land. Operating and maintenance expense on non-cancelable operating leases totaled $6 million , $7 million and $6 million for the year-ended December 31 , 2016 , 2015 and 2014 , respectively. Maintenance, Service and Other Contracts Sierra Pacific has long-term service agreements for the performance of maintenance on generation units. Obligation amounts are based on estimated usage. The estimated expiration of these service agreements range from 2017 to 2039 .

Preferred Stock (Notes)

Preferred Stock (Notes)	12 Months Ended
	Dec. 31, 2016
PacifiCorp [Member]
Class of Stock [Line Items]
Preferred Stock [Text Block]	Preferred Stock PacifiCorp has 3,500 thousand shares of Serial Preferred Stock authorized at the stated value of $100 per share. PacifiCorp had 24 thousand shares of Serial Preferred Stock issued and outstanding as of December 31, 2016 and 2015 . The outstanding preferred stock series are non-redeemable and have annual dividend rates of 6.00% and 7.00% . In the event of voluntary liquidation, all preferred stock is entitled to stated value or a specified preference amount per share plus accrued dividends. Upon involuntary liquidation, all preferred stock is entitled to stated value plus accrued dividends. Dividends on all preferred stock are cumulative. Holders also have the right to elect members to the PacifiCorp Board of Directors in the event dividends payable are in default in an amount equal to four full quarterly payments. PacifiCorp also has 16 million shares of No Par Serial Preferred Stock and 127 thousand shares of 5% Preferred Stock authorized, but no shares were issued or outstanding as of December 31, 2016 and 2015 .

BHE Shareholders' Equity (Notes

BHE Shareholders' Equity (Notes)	12 Months Ended
	Dec. 31, 2016
Stockholders' Equity Note [Abstract]
BHE Shareholders' Equity [Text Block]	BHE Shareholders' Equity Common Stock On March 14, 2000, and as amended on December 7, 2005, BHE 's shareholders entered into a Shareholder Agreement that provides specific rights to certain shareholders. One of these rights allows certain shareholders the ability to put their common shares back to BHE at the then current fair value dependent on certain circumstances controlled by BHE . On February 17, 2017, BHE repurchased from certain family interests of Mr. Walter Scott, Jr. 35,000 shares of its common stock for $19 million . On February 17, 2015, BHE repurchased from certain family interests of Mr. Walter Scott, Jr. 75,000 shares of its common stock for $36 million . Restricted Net Assets BHE has maximum debt-to-total capitalization percentage restrictions imposed by its senior unsecured credit facilities expiring in June 2019 which, in certain circumstances, limit BHE 's ability to make cash dividends or distributions. As a result of this restriction, BHE has restricted net assets of $15.1 billion as of December 31, 2016 . Certain of BHE 's subsidiaries have restrictions on their ability to dividend, loan or advance funds to BHE due to specific legal or regulatory restrictions, including, but not limited to, maximum debt-to-total capitalization percentages and commitments made to state commissions or federal agencies in connection with past acquisitions. As a result of these restrictions, BHE 's subsidiaries had restricted net assets of $17.6 billion as of December 31, 2016 .

Common Shareholder's Equity Com

Common Shareholder's Equity Common Shareholder's Equity (Notes)	12 Months Ended
	Dec. 31, 2016
Class of Stock [Line Items]
Common Shareholder's Equity [Text Block]	BHE Shareholders' Equity Common Stock On March 14, 2000, and as amended on December 7, 2005, BHE 's shareholders entered into a Shareholder Agreement that provides specific rights to certain shareholders. One of these rights allows certain shareholders the ability to put their common shares back to BHE at the then current fair value dependent on certain circumstances controlled by BHE . On February 17, 2017, BHE repurchased from certain family interests of Mr. Walter Scott, Jr. 35,000 shares of its common stock for $19 million . On February 17, 2015, BHE repurchased from certain family interests of Mr. Walter Scott, Jr. 75,000 shares of its common stock for $36 million . Restricted Net Assets BHE has maximum debt-to-total capitalization percentage restrictions imposed by its senior unsecured credit facilities expiring in June 2019 which, in certain circumstances, limit BHE 's ability to make cash dividends or distributions. As a result of this restriction, BHE has restricted net assets of $15.1 billion as of December 31, 2016 . Certain of BHE 's subsidiaries have restrictions on their ability to dividend, loan or advance funds to BHE due to specific legal or regulatory restrictions, including, but not limited to, maximum debt-to-total capitalization percentages and commitments made to state commissions or federal agencies in connection with past acquisitions. As a result of these restrictions, BHE 's subsidiaries had restricted net assets of $17.6 billion as of December 31, 2016 .
PacifiCorp [Member]
Class of Stock [Line Items]
Common Shareholder's Equity [Text Block]	Common Shareholder's Equity In February 2017, PacifiCorp declared a dividend of $100 million payable to PPW Holdings LLC, a wholly owned subsidiary of BHE and PacifiCorp's direct parent company ("PPW Holdings") in March 2017. Through PPW Holdings, BHE is the sole shareholder of PacifiCorp's common stock. The state regulatory orders that authorized BHE's acquisition of PacifiCorp contain restrictions on PacifiCorp's ability to pay dividends to the extent that they would reduce PacifiCorp's common equity below specified percentages of defined capitalization. As of December 31, 2016 , the most restrictive of these commitments prohibits PacifiCorp from making any distribution to PPW Holdings or BHE without prior state regulatory approval to the extent that it would reduce PacifiCorp's common equity below 44% of its total capitalization, excluding short-term debt and current maturities of long-term debt. The terms of this commitment treat 50% of PacifiCorp's remaining balance of preferred stock in existence prior to the acquisition of PacifiCorp by BHE as common equity. As of December 31, 2016 , PacifiCorp's actual common equity percentage, as calculated under this measure, was 51% , and PacifiCorp would have been permitted to dividend $1.9 billion under this commitment. These commitments also restrict PacifiCorp from making any distributions to either PPW Holdings or BHE if PacifiCorp's senior unsecured debt rating is BBB- or lower by Standard & Poor's Rating Services or Fitch Ratings or Baa3 or lower by Moody's Investor Service, as indicated by two of the three rating services. As of December 31, 2016 , PacifiCorp met the minimum required senior unsecured debt ratings for making distributions. PacifiCorp is also subject to a maximum debt-to-total capitalization percentage under various financing agreements as further discussed in Note 6 .

Components of Accumulated Other

Components of Accumulated Other Comprehensive Loss, Net (Notes)	12 Months Ended
	Dec. 31, 2016
Schedule of accumulated other comprehensive income (loss)
Comprehensive Income (Loss)	Components of Accumulated Other Comprehensive Loss, Net The following table shows the change in accumulated other comprehensive loss attributable to BHE shareholders by each component of other comprehensive income (loss), net of applicable income taxes, for the year ended December 31, (in millions): Accumulated Unrealized Other Unrecognized Foreign Gains on Unrealized Comprehensive Amounts on Currency Available- Gains on Loss Attributable Retirement Translation For-Sale Cash Flow To BHE Benefits Adjustment Securities Hedges Shareholders, Net Balance, December 31, 2013 $ (559 ) $ (98 ) $ 524 $ 36 $ (97 ) Other comprehensive income 69 (314 ) (134 ) (18 ) (397 ) Balance, December 31, 2014 (490 ) (412 ) 390 18 (494 ) Other comprehensive income (loss) 52 (680 ) 225 (11 ) (414 ) Balance, December 31, 2015 (438 ) (1,092 ) 615 7 (908 ) Other comprehensive income (loss) (9 ) (583 ) (30 ) 19 (603 ) Balance, December 31, 2016 $ (447 ) $ (1,675 ) $ 585 $ 26 $ (1,511 ) Reclassifications from AOCI to net income for the years ended December 31, 2016 , 2015 and 2014 were insignificant. For information regarding cash flow hedge reclassifications from AOCI to net income in their entirety, refer to Note 14 . Additionally, refer to the "Foreign Operations" discussion in Note 12 for information about unrecognized amounts on retirement benefits reclassifications from AOCI that do not impact net income in their entirety.
PacifiCorp [Member]
Schedule of accumulated other comprehensive income (loss)
Comprehensive Income (Loss)	Components of Accumulated Other Comprehensive Loss, Net Accumulated other comprehensive loss, net consists of unrecognized amounts on retirement benefits, net of tax, of $12 million and $11 million as of December 31, 2016 and 2015 , respectively.
MidAmerican Energy Company [Member]
Schedule of accumulated other comprehensive income (loss)
Comprehensive Income (Loss)	Components of Accumulated Other Comprehensive Loss, Net The following table shows the change in accumulated other comprehensive loss by each component of other comprehensive income, net of applicable income taxes, for the years ended December 31, 2016 and 2015 (in millions): Unrealized Unrealized Accumulated Losses on Losses Other Available-For-Sale on Cash Flow Comprehensive Securities Hedges Loss, Net Balance, December 31, 2014 $ (3 ) $ (20 ) $ (23 ) Other comprehensive loss — (7 ) (7 ) Balance, December 31, 2015 $ (3 ) $ (27 ) $ (30 ) Other comprehensive income 3 — 3 Dividend (Note 3) — 27 27 Balance, December 31, 2016 $ — $ — $ — For information regarding cash flow hedge reclassifications from AOCI to net income in their entirety for the years ended December 31, 2016 , 2015 and 2014 , refer to Note 13 .
MidAmerican Funding, LLC and Subsidiaries [Domain]
Schedule of accumulated other comprehensive income (loss)
Comprehensive Income (Loss)	Components of Accumulated Other Comprehensive Loss, Net Refer to Note 16 of MidAmerican Energy's Notes to Financial Statements.

Variable-Interest Entities Vari

Variable-Interest Entities Variable-Interest Entities (Notes)	12 Months Ended
	Dec. 31, 2016
PacifiCorp [Member]
Schedule of Equity Method Investments [Line Items]
Variable Interest Entity Disclosure [Text Block]	Variable-Interest Entities PacifiCorp holds an undivided interest in 50% of the Hermiston generating facility (refer to Note 4). Prior to the expiration of a power purchase agreement in July 2016, PacifiCorp dictated when the generating facility operated, procured 100% of the natural gas for the generating facility and subsequently received 100% of the generated electricity, 50% of which was acquired through a power purchase agreement that expired. As a result, PacifiCorp held a variable interest in the joint owner of the remaining 50% of the facility and was the primary beneficiary. With the expiration of the power purchase agreement, PacifiCorp no longer holds a variable interest in the joint owner. PacifiCorp was unable to obtain the information necessary to previously consolidate the entity because the entity did not supply the information due to the lack of a contractual obligation to do so. Cost of the electricity purchased from the joint owner was $20 million , $39 million and $38 million during each of the years ended December 31, 2016 , 2015 and 2014 , respectively. The entity is operated by the equity owners and PacifiCorp has no risk of loss in relation to the entity in the event of a disaster. PacifiCorp holds a two-thirds interest in Bridger Coal Company ("Bridger Coal"), which supplies coal to the Jim Bridger generating facility that is owned two-thirds by PacifiCorp and one-third by PacifiCorp's joint venture partner in Bridger Coal. PacifiCorp purchases two-thirds of the coal produced by Bridger Coal, while the remaining coal is purchased by the joint venture partner. The power to direct the activities that most significantly impact Bridger Coal's economic performance are shared with the joint venture partner. Each joint venture partner is jointly and severally liable for the obligations of Bridger Coal. Bridger Coal's necessary working capital to carry out its mining operations is financed by contributions from PacifiCorp and its joint venture partner. PacifiCorp's equity investment in Bridger Coal was $165 million and $190 million as of December 31, 2016 and 2015 , respectively. Refer to Note 18 for information regarding related-party transactions with Bridger Coal.

Noncontrolling Interests (Notes

Noncontrolling Interests (Notes)	12 Months Ended
	Dec. 31, 2016
Noncontrolling Interest [Line Items]
Noncontrolling Interests [Text Block]	Noncontrolling Interests Included in noncontrolling interests on the Consolidated Balance Sheets are preferred securities of subsidiaries of $58 million as of December 31, 2016 and 2015 , consisting of $56 million of 8.061% cumulative preferred securities of Northern Electric plc., a subsidiary of Northern Powergrid , which are redeemable in the event of the revocation of Northern Electric plc.'s electricity distribution license by the Secretary of State, and $2 million of nonredeemable preferred stock of PacifiCorp.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Noncontrolling Interest [Line Items]
Other, Net [Text Block]	Other Income and (Expense) - Other, Net Other, net, as shown on the Consolidated Statements of Operations, includes the following other income (expense) items for the years ended December 31 (in millions): 2016 2015 2014 Corporate-owned life insurance income $ 8 $ 4 $ 8 Gain on redemption of auction rate securities 5 — — Gains on sales of assets and other investments 3 13 — Leveraged leases — 1 5 Other, net 3 1 5 Total $ 19 $ 19 $ 18 MidAmerican Funding recognized a $13 million pre-tax gain on the sale of an investment in a generating facility lease in 2015.

Segment Information (Notes)

Segment Information (Notes)	12 Months Ended
	Dec. 31, 2016
Segment Reporting Information [Line Items]
Segment Information [Text Block]	Segment Information The Company's reportable segments with foreign operations include Northern Powergrid , whose business is principally in the United Kingdom, BHE Transmission , whose business includes operations in Canada, and BHE Renewables , whose business includes operations in the Philippines. Intersegment eliminations and adjustments, including the allocation of goodwill, have been made. Effective January 1, 2016, MidAmerican Energy transferred the assets and liabilities of its unregulated retail services business to MidAmerican Energy Services, LLC, a subsidiary of BHE. Prior period amounts have been changed to reflect this activity in BHE and Other. Information related to the Company's reportable segments is shown below (in millions): Years Ended December 31, 2016 2015 2014 Operating revenue: PacifiCorp $ 5,201 $ 5,232 $ 5,252 MidAmerican Funding 2,631 2,515 2,844 NV Energy 2,895 3,351 3,241 Northern Powergrid 995 1,140 1,283 BHE Pipeline Group 978 1,016 1,078 BHE Transmission 502 592 62 BHE Renewables 743 728 623 HomeServices 2,801 2,526 2,144 BHE and Other (1) 676 780 799 Total operating revenue $ 17,422 $ 17,880 $ 17,326 Depreciation and amortization: PacifiCorp $ 783 $ 780 $ 745 MidAmerican Funding 479 407 351 NV Energy 421 410 379 Northern Powergrid 200 202 198 BHE Pipeline Group 206 204 196 BHE Transmission 241 185 13 BHE Renewables 230 216 152 HomeServices 31 29 29 BHE and Other (1) — (5 ) (6 ) Total depreciation and amortization $ 2,591 $ 2,428 $ 2,057 Operating income: PacifiCorp $ 1,427 $ 1,344 $ 1,308 MidAmerican Funding 566 451 395 NV Energy 770 812 791 Northern Powergrid 494 593 674 BHE Pipeline Group 455 464 439 BHE Transmission 92 260 16 BHE Renewables 256 255 314 HomeServices 212 184 125 BHE and Other (1) (21 ) (35 ) (16 ) Total operating income 4,251 4,328 4,046 Interest expense (1,854 ) (1,904 ) (1,711 ) Capitalized interest 139 74 89 Allowance for equity funds 158 91 98 Interest and dividend income 120 107 38 Other, net 36 39 42 Total income before income tax expense and equity income (loss) $ 2,850 $ 2,735 $ 2,602 Years Ended December 31, 2016 2015 2014 Interest expense: PacifiCorp $ 381 $ 383 $ 386 MidAmerican Funding 218 206 197 NV Energy 250 262 283 Northern Powergrid 136 145 151 BHE Pipeline Group 50 66 76 BHE Transmission 153 146 14 BHE Renewables 198 193 175 HomeServices 2 3 4 BHE and Other (1) 466 500 425 Total interest expense $ 1,854 $ 1,904 $ 1,711 Income tax expense (benefit): PacifiCorp $ 341 $ 328 $ 310 MidAmerican Funding (139 ) (150 ) (122 ) NV Energy 200 207 195 Northern Powergrid 22 35 110 BHE Pipeline Group 163 158 149 BHE Transmission 26 63 28 BHE Renewables (32 ) 41 65 HomeServices 81 72 44 BHE and Other (1) (259 ) (304 ) (190 ) Total income tax expense (benefit) $ 403 $ 450 $ 589 Capital expenditures: PacifiCorp $ 903 $ 916 $ 1,066 MidAmerican Funding 1,637 1,448 1,527 NV Energy 529 571 558 Northern Powergrid 579 674 675 BHE Pipeline Group 226 240 257 BHE Transmission 466 966 222 BHE Renewables 719 1,034 2,221 HomeServices 20 16 17 BHE and Other 11 10 12 Total capital expenditures $ 5,090 $ 5,875 $ 6,555 As of December 31, 2016 2015 2014 Property, plant and equipment, net: PacifiCorp $ 19,162 $ 19,039 $ 18,755 MidAmerican Funding 12,835 11,737 10,535 NV Energy 9,825 9,767 9,648 Northern Powergrid 5,148 5,790 5,599 BHE Pipeline Group 4,423 4,345 4,286 BHE Transmission 5,810 5,301 5,567 BHE Renewables 5,302 4,805 4,897 HomeServices 78 70 68 BHE and Other (74 ) (85 ) (107 ) Total property, plant and equipment, net $ 62,509 $ 60,769 $ 59,248 Total assets: PacifiCorp $ 23,563 $ 23,550 $ 23,404 MidAmerican Funding 17,571 16,315 15,164 NV Energy 14,320 14,656 14,256 Northern Powergrid 6,433 7,317 7,059 BHE Pipeline Group 5,144 4,953 4,951 BHE Transmission 8,378 7,553 7,979 BHE Renewables 7,010 5,892 6,082 HomeServices 1,776 1,705 1,622 BHE and Other 1,245 1,677 1,299 Total assets $ 85,440 $ 83,618 $ 81,816 Years Ended December 31, 2016 2015 2014 Operating revenue by country: United States $ 15,895 $ 16,121 $ 15,857 United Kingdom 995 1,140 1,281 Canada 506 600 78 Philippines and other 26 19 110 Total operating revenue by country $ 17,422 $ 17,880 $ 17,326 Income before income tax expense and equity income by country: United States $ 2,264 $ 2,034 $ 2,001 United Kingdom 382 472 557 Canada 135 165 4 Philippines and other 69 64 40 Total income before income tax expense and equity income by country: $ 2,850 $ 2,735 $ 2,602 As of December 31, 2016 2015 2014 Property, plant and equipment, net by country: United States $ 51,671 $ 49,680 $ 47,918 United Kingdom 5,020 5,757 5,563 Canada 5,803 5,298 5,570 Philippines and other 15 34 197 Total property, plant and equipment, net by country $ 62,509 $ 60,769 $ 59,248 (1) The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other , relate to other corporate entities, including MidAmerican Energy Services, LLC, corporate functions and intersegment eliminations. The following table shows the change in the carrying amount of goodwill by reportable segment for the years ended December 31, 2016 and 2015 (in millions): BHE BHE MidAmerican NV Northern Pipeline BHE BHE Home- and PacifiCorp Funding Energy Powergrid Group Transmission Renewables Services Other Total December 31, 2014 $ 1,129 $ 2,102 $ 2,369 $ 1,100 $ 127 $ 1,657 $ 95 $ 761 $ 3 $ 9,343 Acquisitions — — — — — 44 — 33 — 77 Foreign currency translation — — — (44 ) — (273 ) — — (1 ) (318 ) Other — — — — (26 ) — — — — (26 ) December 31, 2015 1,129 2,102 2,369 1,056 101 1,428 95 794 2 9,076 Acquisitions — — — — — 4 — 46 — 50 Foreign currency translation — — — (126 ) — 42 — — (2 ) (86 ) Other — — — — (26 ) (4 ) — — — (30 ) December 31, 2016 $ 1,129 $ 2,102 $ 2,369 $ 930 $ 75 $ 1,470 $ 95 $ 840 $ — $ 9,010
MidAmerican Energy Company [Member]
Segment Reporting Information [Line Items]
Segment Information [Text Block]	Segment Information MidAmerican Energy has identified two reportable operating segments: regulated electric and regulated gas. The previously reported nonregulated energy segment consisted substantially of MidAmerican Energy's unregulated retail services business, which was transferred to a subsidiary of BHE and is excluded from the information below related to the statements of operations for all periods presented. The regulated electric segment derives most of its revenue from regulated retail sales of electricity to residential, commercial, and industrial customers and from wholesale sales. The regulated gas segment derives most of its revenue from regulated retail sales of natural gas to residential, commercial, and industrial customers and also obtains revenue by transporting gas owned by others through its distribution system. Pricing for regulated electric and regulated gas sales are established separately by regulatory agencies; therefore, management also reviews each segment separately to make decisions regarding allocation of resources and in evaluating performance. Common operating costs, interest income, interest expense and income tax expense are allocated to each segment based on certain factors, which primarily relate to the nature of the cost. Refer to Note 10 for a discussion of items affecting income tax (benefit) expense for the regulated electric and gas operating segments. The following tables provide information on a reportable segment basis (in millions): Years Ended December 31, 2016 2015 2014 Operating revenue: Regulated electric $ 1,985 $ 1,837 $ 1,817 Regulated gas 637 661 996 Other 3 4 9 Total operating revenue $ 2,625 $ 2,502 $ 2,822 Depreciation and amortization: Regulated electric $ 436 $ 366 $ 312 Regulated gas 43 41 39 Total depreciation and amortization $ 479 $ 407 $ 351 Operating income: Regulated electric $ 497 $ 385 $ 319 Regulated gas 68 64 75 Total operating income $ 565 $ 449 $ 394 Interest expense: Regulated electric $ 178 $ 166 $ 157 Regulated gas 18 17 17 Total interest expense $ 196 $ 183 $ 174 Income tax (benefit) expense from continuing operations: Regulated electric $ (156 ) $ (163 ) $ (138 ) Regulated gas 22 16 22 Other 2 — — Total income tax (benefit) expense from continuing operations $ (132 ) $ (147 ) $ (116 ) Net income: Regulated electric $ 512 $ 413 $ 361 Regulated gas 32 33 40 Other (2 ) — — Income from continuing operations 542 446 401 Income on discontinued operations — 16 16 Net income $ 542 $ 462 $ 417 Years Ended December 31, 2016 2015 2014 Utility construction expenditures: Regulated electric $ 1,564 $ 1,365 $ 1,429 Regulated gas 72 81 97 Total utility construction expenditures $ 1,636 $ 1,446 $ 1,526 As of December 31, 2016 2015 2014 Total assets: Regulated electric $ 14,113 $ 12,970 $ 11,850 Regulated gas 1,345 1,251 1,217 Other 1 164 167 Total assets $ 15,459 $ 14,385 $ 13,234
MidAmerican Funding, LLC and Subsidiaries [Domain]
Segment Reporting Information [Line Items]
Segment Information [Text Block]	Segment Information MidAmerican Funding has identified two reportable operating segments: regulated electric and regulated gas. The previously reported nonregulated energy segment consisted substantially of MidAmerican Energy's unregulated retail services business, which was transferred to a subsidiary of BHE and is excluded from the information below related to the statements of operations for all periods presented. The regulated electric segment derives most of its revenue from regulated retail sales of electricity to residential, commercial, and industrial customers and from wholesale sales. The regulated gas segment derives most of its revenue from regulated retail sales of natural gas to residential, commercial, and industrial customers and also obtains revenue by transporting gas owned by others through its distribution system. Pricing for regulated electric and regulated gas sales are established separately by regulatory agencies; therefore, management also reviews each segment separately to make decisions regarding allocation of resources and in evaluating performance. Common operating costs, interest income, interest expense and income tax expense are allocated to each segment based on certain factors, which primarily relate to the nature of the cost. "Other" in the tables below consists of the nonregulated subsidiaries of MidAmerican Funding not engaged in the energy business and parent company interest expense. Refer to Note 10 for a discussion of items affecting income tax (benefit) expense for the regulated electric and gas operating segments. The following tables provide information on a reportable segment basis (in millions): Years Ended December 31, 2016 2015 2014 Operating revenue: Regulated electric $ 1,985 $ 1,837 $ 1,817 Regulated gas 637 661 996 Other 9 17 31 Total operating revenue $ 2,631 $ 2,515 $ 2,844 Depreciation and amortization: Regulated electric $ 436 $ 366 $ 312 Regulated gas 43 41 39 Total depreciation and amortization $ 479 $ 407 $ 351 Operating income: Regulated electric $ 497 $ 385 $ 319 Regulated gas 68 64 75 Other 1 2 1 Total operating income $ 566 $ 451 $ 395 Interest expense: Regulated electric $ 178 $ 166 $ 157 Regulated gas 18 17 17 Other 23 23 23 Total interest expense $ 219 $ 206 $ 197 Income tax (benefit) expense from continuing operations: Regulated electric $ (156 ) $ (163 ) $ (138 ) Regulated gas 22 16 22 Other (5 ) (3 ) (6 ) Total income tax (benefit) expense from continuing operations $ (139 ) $ (150 ) $ (122 ) Net income: Regulated electric $ 512 $ 413 $ 361 Regulated gas 32 33 40 Other (12 ) (4 ) (8 ) Income from continuing operations 532 442 393 Income on discontinued operations — 16 16 Net income $ 532 $ 458 $ 409 Utility construction expenditures: Regulated electric $ 1,564 $ 1,365 $ 1,429 Regulated gas 72 81 97 Total utility construction expenditures $ 1,636 $ 1,446 $ 1,526 As of December 31, 2016 2015 2014 Total assets: Regulated electric $ 15,304 $ 14,161 $ 13,041 Regulated gas 1,424 1,330 1,296 Other 19 183 185 Total assets $ 16,747 $ 15,674 $ 14,522 Goodwill by reportable segment as of December 31, 2016 and 2015 , was as follows (in millions): Regulated electric $ 1,191 Regulated gas 79 Total $ 1,270
Sierra Pacific Power Company [Member]
Segment Reporting Information [Line Items]
Segment Information [Text Block]	Segment Information Sierra Pacific has identified two reportable operating segments: regulated electric and regulated natural gas. The regulated electric segment derives most of its revenue from regulated retail sales of electricity to residential, commercial, and industrial customers and from wholesale sales. The regulated natural gas segment derives most of its revenue from regulated retail sales of natural gas to residential, commercial, and industrial customers and also obtains revenue by transporting natural gas owned by others through its distribution system. Pricing for regulated electric and regulated natural gas sales are established separately by the PUCN; therefore, management also reviews each segment separately to make decisions regarding allocation of resources and in evaluating performance. Sierra Pacific believes presenting gross margin allows the reader to assess the impact of Sierra Pacific 's regulatory treatment and its overall regulatory environment on a consistent basis and is meaningful. Gross margin is calculated as operating revenue less cost of fuel, energy and capacity and natural gas purchased for resale ("cost of sales"). The following tables provide information on a reportable segment basis for the years ended December 31 (in millions): Years Ended December 31, 2016 2015 2014 Operating revenue: Regulated electric $ 702 $ 810 $ 779 Regulated gas 110 137 125 Total operating revenue $ 812 $ 947 $ 904 Cost of sales: Regulated electric $ 265 $ 374 $ 361 Regulated gas 55 84 76 Total cost of sales $ 320 $ 458 $ 437 Gross margin: Regulated electric $ 437 $ 436 $ 418 Regulated gas 55 53 49 Total gross margin $ 492 $ 489 $ 467 Operating and maintenance: Regulated electric $ 153 $ 149 $ 143 Regulated gas 17 18 19 Total operating and maintenance $ 170 $ 167 $ 162 Depreciation and amortization: Regulated electric $ 101 $ 96 $ 90 Regulated gas 17 17 15 Total depreciation and amortization $ 118 $ 113 $ 105 Operating income: Regulated electric $ 161 $ 168 $ 165 Regulated gas 19 16 13 Total operating income $ 180 $ 184 $ 178 Interest expense: Regulated electric $ 49 $ 56 $ 57 Regulated gas 5 5 4 Total interest expense $ 54 $ 61 $ 61 Income tax expense: Regulated electric $ 44 $ 43 $ 43 Regulated gas 5 4 4 Total income tax expense $ 49 $ 47 $ 47 Years Ended December 31, 2016 2015 2014 Capital expenditures: Regulated electric $ 176 $ 229 $ 168 Regulated gas 18 23 18 Total capital expenditures $ 194 $ 252 $ 186 As of December 31, Total assets: 2016 2015 2014 Regulated electric $ 3,119 $ 3,060 $ 2,984 Regulated gas 314 316 322 Regulated common assets (1) 60 111 30 Total assets $ 3,493 $ 3,487 $ 3,336 (1) Consists principally of cash and cash equivalents not included in either the regulated electric or regulated natural gas segments.

Subsequent Events (MEC) Subsequ

Subsequent Events (MEC) Subsequent Events (MEC)	12 Months Ended
	Dec. 31, 2016
MidAmerican Funding, LLC and Subsidiaries [Domain]
Subsequent Event [Line Items]
Subsequent Events [Text Block]	Refer to Note 21 of MidAmerican Energy's Notes to Financial Statements.
MidAmerican Energy Company [Member]
Subsequent Event [Line Items]
Subsequent Events [Text Block]	Subsequent Events In February 2017, MidAmerican Energy issued $375 million of its 3.10% First Mortgage Bonds due May 2027 and $475 million of its 3.95% First Mortgage Bonds due August 2047. An amount equal to the net proceeds will be used to finance capital expenditures, disbursed during the period from February 2, 2016 to February 1, 2017, with respect to investments in MidAmerican Energy's 551-megawatt Wind X and 2,000-megawatt Wind XI projects, which were previously financed with MidAmerican Energy's general funds. In January 2017, MidAmerican Energy provided notice to holders of its $250 million of 5.95% Senior Notes due July 2017 that MidAmerican Energy would redeem such notes in full through optional redemption on February 27, 2017.

Unaudited Quarterly Operating R

Unaudited Quarterly Operating Results Unaudited Quarterly Operating Results (Notes)	12 Months Ended
	Dec. 31, 2016
MidAmerican Energy Company [Member]
Quarterly Operating Results [Line Items]
Quarterly Financial Information [Text Block]	Unaudited Quarterly Operating Results 2016 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 625 $ 584 $ 795 $ 621 Operating income 100 139 284 42 Net income 76 131 320 15 2015 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 722 $ 572 $ 680 $ 528 Operating income 100 112 208 29 Income from continuing operations 90 126 233 (3 ) Income on discontinued operations 4 5 1 6 Net income 94 131 234 3 Quarterly data reflect seasonal variations common to a Midwest utility.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Quarterly Operating Results [Line Items]
Quarterly Financial Information [Text Block]	Unaudited Quarterly Operating Results 2016 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 626 $ 585 $ 797 $ 623 Operating income 100 140 284 42 Net income 73 127 318 14 2015 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 727 $ 576 $ 681 $ 531 Operating income 101 112 209 29 Income from continuing operations 95 124 230 (7 ) Income on discontinued operations 4 5 1 6 Net income 99 129 231 (1 ) Quarterly data reflect seasonal variations common to a Midwest utility.
Nevada Power Company [Member]
Quarterly Operating Results [Line Items]
Quarterly Financial Information [Text Block]	Unaudited Quarterly Operating Results (in millions) Three-Month Periods Ended March 31, June 30, September 30, December 31, 2016 2016 2016 2016 Operating revenues $ 399 $ 525 $ 766 $ 393 Operating income 46 141 324 69 Net income 3 66 188 22 Three-Month Periods Ended March 31, June 30, September 30, December 31, 2015 2015 2015 2015 Operating revenues $ 459 $ 607 $ 878 $ 458 Operating income 74 136 329 74 Net income 24 60 187 17
Sierra Pacific Power Company [Member]
Quarterly Operating Results [Line Items]
Quarterly Financial Information [Text Block]	Unaudited Quarterly Operating Results (in millions) Three-Month Periods Ended March 31, June 30, September 30, December 31, 2016 2016 2016 2016 Regulated electric operating revenue $ 170 $ 162 $ 207 $ 163 Regulated natural gas operating revenue 47 19 15 29 Operating income 41 28 69 42 Net income 17 10 38 19 Three-Month Periods Ended March 31, June 30, September 30, December 31, 2015 2015 2015 2015 Regulated electric operating revenue $ 196 $ 201 $ 228 $ 185 Regulated natural gas operating revenue 50 26 18 43 Operating income 43 37 66 38 Net income 19 16 33 15

Condensed Financial Statements

Condensed Financial Statements (Notes)	12 Months Ended
	Dec. 31, 2016
Condensed Financial Statements, Captions [Line Items]
Condensed Financial Statements [Text Block]	Schedule I Berkshire Hathaway Energy Company Parent Company Only Condensed Balance Sheets As of December 31, (Amounts in millions) 2016 2015 ASSETS Current assets: Cash and cash equivalents $ 33 $ 23 Accounts receivable 21 16 Notes receivable - affiliate 105 — Income tax receivable — 167 Other current assets 2 2 Total current assets 161 208 Investments in subsidiaries 33,400 32,505 Other investments 1,338 1,389 Goodwill 1,221 1,221 Other assets 1,171 1,340 Total assets $ 37,291 $ 36,663 LIABILITIES AND EQUITY Current liabilities: Accounts payable and other current liabilities $ 357 $ 306 Notes payable - affiliate 194 — Short-term debt 834 253 Current portion of BHE senior debt 400 — Total current liabilities 1,785 559 BHE senior debt 7,418 7,814 BHE junior subordinated debentures 944 2,944 Notes payable - affiliate 1,859 1,985 Other long-term liabilities 942 946 Total liabilities 12,948 14,248 Equity: BHE shareholders' equity: Common stock - 115 shares authorized, no par value, 77 shares issued and outstanding — — Additional paid-in capital 6,390 6,403 Retained earnings 19,448 16,906 Accumulated other comprehensive loss, net (1,511 ) (908 ) Total BHE shareholders' equity 24,327 22,401 Noncontrolling interest 16 14 Total equity 24,343 22,415 Total liabilities and equity $ 37,291 $ 36,663 The accompanying notes are an integral part of this financial statement schedule. Schedule I Berkshire Hathaway Energy Company Parent Company Only (continued) Condensed Statements of Operations For the years ended December 31, (Amounts in millions) 2016 2015 2014 Operating costs and expenses: General and administration $ 51 $ 58 $ 51 Depreciation and amortization 4 3 3 Total operating costs and expenses 55 61 54 Operating loss (55 ) (61 ) (54 ) Other income (expense): Interest expense (527 ) (556 ) (476 ) Other, net 37 14 4 Total other income (expense) (490 ) (542 ) (472 ) Loss before income tax benefit and equity income (545 ) (603 ) (526 ) Income tax benefit (285 ) (330 ) (221 ) Equity income 2,805 2,646 2,402 Net income 2,545 2,373 2,097 Net income attributable to noncontrolling interest 3 3 2 Net income attributable to BHE shareholders $ 2,542 $ 2,370 $ 2,095 The accompanying notes are an integral part of this financial statement schedule. Schedule I Berkshire Hathaway Energy Company Parent Company Only (continued) Condensed Statements of Comprehensive Income For the years ended December 31, (Amounts in millions) 2016 2015 2014 Net income $ 2,545 $ 2,373 $ 2,097 Other comprehensive loss, net of tax (603 ) (414 ) (397 ) Comprehensive income 1,942 1,959 1,700 Comprehensive income attributable to noncontrolling interests 3 3 2 Comprehensive income attributable to BHE shareholders $ 1,939 $ 1,956 $ 1,698 The accompanying notes are an integral part of this financial statement schedule. Schedule I Berkshire Hathaway Energy Company Parent Company Only (continued) Condensed Statements of Cash Flows For the years ended December 31, (Amounts in millions) 2016 2015 2014 Cash flows from operating activities $ 2,760 $ 2,528 $ 1,937 Cash flows from investing activities: Investments in subsidiaries (1,080 ) (1,506 ) (4,937 ) Purchases of investments (24 ) (36 ) (56 ) Proceeds from sale of investments 20 47 35 Notes receivable from affiliate, net (307 ) 19 (55 ) Other, net (5 ) (7 ) (7 ) Net cash flows from investing activities (1,396 ) (1,483 ) (5,020 ) Cash flows from financing activities: Proceeds from BHE senior debt — — 1,478 Proceeds from BHE junior subordinated debentures — — 1,500 Proceeds from issuance of BHE common stock — — — Repayments of BHE senior debt — — (250 ) Repayments of BHE subordinated debt (2,000 ) (850 ) (300 ) Common stock purchases — (36 ) — Net proceeds from (repayments of) short-term debt 581 (142 ) 395 Notes payable to affiliate, net 69 4 (30 ) Other, net (4 ) (1 ) 1 Net cash flows from financing activities (1,354 ) (1,025 ) 2,794 Net change in cash and cash equivalents 10 20 (289 ) Cash and cash equivalents at beginning of year 23 3 292 Cash and cash equivalents at end of year $ 33 $ 23 $ 3 The accompanying notes are an integral part of this financial statement schedule. Schedule I BERKSHIRE HATHAWAY ENERGY COMPANY NOTES TO CONDENSED FINANCIAL STATEMENTS Basis of Presentation - The condensed financial information of BHE investments in subsidiaries are presented under the equity method of accounting. Under this method, the assets and liabilities of subsidiaries are not consolidated. The investments in subsidiaries are recorded in the Condensed Balance Sheets. The income from operations of subsidiaries is reported on a net basis as equity income in the Condensed Statements of Operations. Other investments - BHE 's investment in BYD Company Limited ("BYD") common stock is accounted for as an available-for-sale security with changes in fair value recognized in AOCI. As of December 31, 2016 and 2015 , the fair value of BHE 's investment in BYD common stock was $1,185 million and $1,238 million , respectively, which resulted in a unrealized gain of $953 million and $1,006 million as of December 31, 2016 and 2015 , respectively. Dividends and distributions from subsidiaries - Cash dividends paid to BHE by its subsidiaries for the years ended December 31, 2016 , 2015 and 2014 were $3.0 billion , $3.0 billion and $2.3 billion , respectively. In January and February 2017 , BHE received cash dividends from its subsidiaries totaling $160 million . Guarantees and commitments - BHE has issued guarantees up to a maximum of $336 million in support of various obligations of consolidated subsidiaries and commitments to provide equity contributions in support of renewable tax equity investments totaling $288 million . See the notes to the consolidated BHE financial statements in Part II, Item 8 for other disclosures regarding long-term obligations (Notes 8, 9 and 10) and shareholders' equity (Note 17).
MidAmerican Funding LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Condensed Financial Statements [Text Block]	MIDAMERICAN FUNDING, LLC PARENT COMPANY ONLY NOTES TO CONDENSED FINANCIAL STATEMENTS Incorporated by reference are MidAmerican Funding, LLC and Subsidiaries Consolidated Statements of Changes in Equity for the three years ended December 31, 2016 in Part II, Item 8. Basis of Presentation - The condensed financial information of MidAmerican Funding, LLC's ("MidAmerican Funding's") investments in subsidiaries is presented under the equity method of accounting. Under this method, the assets and liabilities of subsidiaries are not consolidated. The investments in and advances to subsidiaries are recorded on the Condensed Balance Sheets. The income from operations of the subsidiaries is reported on a net basis as equity in undistributed earnings of subsidiary companies on the Condensed Statements of Operations. Payable to Affiliate - MHC, Inc. ("MHC") settles all obligations of MidAmerican Funding including primarily interest costs on, and repayments of, MidAmerican Funding's long-term debt. Net amounts paid by MHC on behalf of MidAmerican Funding totaled $13 million , $13 million and $13 million for the years 2016 , 2015 and 2014 , respectively. See the notes to the consolidated MidAmerican Funding financial statements in Part II, Item 8 for other disclosures.

Schedule II Consolidated Valuat

Schedule II Consolidated Valuation and Qualifying Accounts (Notes)	12 Months Ended
	Dec. 31, 2016
Valuation and Qualifying Accounts Disclosure [Line Items]
Consolidated Valuation and Qualifying Accounts [Text Block]	Schedule II BERKSHIRE HATHAWAY ENERGY COMPANY CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS FOR THE THREE YEARS ENDED DECEMBER 31, 2016 (Amounts in millions) Column B Column C Column E Balance at Charged Balance Column A Beginning to Acquisition Column D at End Description of Year Income Reserves Deductions of Year Reserves Deducted From Assets To Which They Apply: Reserve for uncollectible accounts receivable: Year ended 2016 $ 31 $ 39 $ — $ (37 ) $ 33 Year ended 2015 37 33 — (39 ) 31 Year ended 2014 33 37 — (33 ) 37 Reserves Not Deducted From Assets (1) : Year ended 2016 $ 13 $ 5 $ — $ (5 ) $ 13 Year ended 2015 11 7 — (5 ) 13 Year ended 2014 9 12 — (10 ) 11 The notes to the consolidated BHE financial statements are an integral part of this financial statement schedule. (1) Reserves not deducted from assets relate primarily to estimated liabilities for losses retained by BHE for workers compensation, public liability and property damage claims.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Valuation and Qualifying Accounts Disclosure [Line Items]
Consolidated Valuation and Qualifying Accounts [Text Block]	MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES MHC INC. AND SUBSIDIARIES CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS FOR THE THREE YEARS ENDED DECEMBER 31, 2016 (Amounts in millions) Column B Column C Column E Balance at Additions Balance Column A Beginning Charged Column D at End Description of Year to Income Deductions of Year Reserves Deducted From Assets To Which They Apply: Reserve for uncollectible accounts receivable: Year ended 2016 $ 6 $ 7 $ (6 ) $ 7 Year ended 2015 $ 7 $ 7 $ (8 ) $ 6 Year ended 2014 $ 10 $ 7 $ (10 ) $ 7 Reserves Not Deducted From Assets (1) : Year ended 2016 $ 13 $ 5 $ (5 ) $ 13 Year ended 2015 $ 11 $ 7 $ (5 ) $ 13 Year ended 2014 $ 9 $ 12 $ (10 ) $ 11 (1) Reserves not deducted from assets include primarily estimated liabilities for losses retained by MidAmerican Funding and MHC for workers compensation, public liability and property damage claims.
MidAmerican Energy Company [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Consolidated Valuation and Qualifying Accounts [Text Block]	MIDAMERICAN ENERGY COMPANY VALUATION AND QUALIFYING ACCOUNTS FOR THE THREE YEARS ENDED DECEMBER 31, 2016 (Amounts in millions) Column B Column C Column E Balance at Additions Balance Column A Beginning Charged Column D at End Description of Year to Income Deductions of Year Reserves Deducted From Assets To Which They Apply: Reserve for uncollectible accounts receivable: Year ended 2016 $ 6 $ 7 $ (6 ) $ 7 Year ended 2015 $ 7 $ 7 $ (8 ) $ 6 Year ended 2014 $ 10 $ 7 $ (10 ) $ 7 Reserves Not Deducted From Assets (1) : Year ended 2016 $ 13 $ 5 $ (5 ) $ 13 Year ended 2015 $ 11 $ 7 $ (5 ) $ 13 Year ended 2014 $ 9 $ 12 $ (10 ) $ 11 (1) Reserves not deducted from assets include estimated liabilities for losses retained by MidAmerican Energy for workers compensation, public liability and property damage claims.

Discontinued Operations Discont

Discontinued Operations Discontinued Operations - Unregulated Retail Services [Member]	12 Months Ended
	Dec. 31, 2016
MidAmerican Funding, LLC and Subsidiaries [Domain]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operations, Disclosure	Discontinued Operations Refer to Note 3 of MidAmerican Energy's Notes to Financial Statements. The transfer of MidAmerican Energy's unregulated retail services business to a subsidiary of BHE repaid $117 million of MHC's note payable to BHE.
MidAmerican Energy Company [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operations, Disclosure	Discontinued Operations On January 1, 2016, MidAmerican Energy transferred the assets and liabilities of its unregulated retail services business to a subsidiary of BHE. The transfer was made at MidAmerican Energy’s carrying value of the assets, liabilities and AOCI as of December 31, 2015, and was recorded by MidAmerican Energy as a noncash dividend. Financial results of the unregulated retail services business for the years ended December 31, 2015 and 2014, respectively, have been reclassified to discontinued operations in the Statements of Operations. Significant line items constituting pre-tax income from discontinued operations and total cash flows from operating activities for the years ended December 31 are as follows (in millions): 2015 2014 Operating revenue $ 905 $ 918 Cost of sales $ 854 $ 863 Cash flows from operating activities $ 30 $ (22 ) Assets, liabilities and equity of the unregulated retail services business reflected in the Balance Sheets as of December 31, 2015 are as follows (in millions): Receivables $ 115 Derivative assets 41 Deferred income taxes 21 Accounts payable (49 ) Derivative liabilities (42 ) Other assets and liabilities, net 4 Accumulated other comprehensive loss, net 27 Equity, excluding accumulated other comprehensive loss, net (117 )

Summary of Significant Accoun42

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
Allowance for Doubtful Accounts [Line Items]
Basis of consolidation and presentation [Policy Text Block]	Basis of Consolidation and Presentation The Consolidated Financial Statements include the accounts of BHE and its subsidiaries in which it holds a controlling financial interest as of the financial statement date. The Consolidated Statements of Operations include the revenue and expenses of any acquired entities from the date of acquisition. Intercompany accounts and transactions have been eliminated.
Use of estimates in preparation of financial statements [Policy Text Block]	Use of Estimates in Preparation of Financial Statements The preparation of the Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; impairment of goodwill; recovery of long-lived assets; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; fair value of assets acquired and liabilities assumed in business combinations; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Consolidated Financial Statements.
Accounting for the effects of certain types of regulation [Policy Text Block]	Accounting for the Effects of Certain Types of Regulation PacifiCorp, MidAmerican Energy, Nevada Power, Sierra Pacific, Northern Natural Gas, Kern River and ALP (the "Regulated Businesses") prepare their financial statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, the Regulated Businesses defer the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future regulated rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in regulated rates occur. The Company continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future regulated rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition that could limit the Regulated Businesses' ability to recover their costs. The Company believes the application of the guidance for regulated operations is appropriate and its existing regulatory assets and liabilities are probable of inclusion in future regulated rates. The evaluation reflects the current political and regulatory climate at both the federal, state and provincial levels. If it becomes no longer probable that the deferred costs or income will be included in future regulated rates, the related regulatory assets and liabilities will be recognized in net income, returned to customers or re-established as accumulated other comprehensive income (loss) ("AOCI").
Fair value measurement [Policy Text Block]	Fair Value Measurements As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange.
Cash equivalent and restricted cash and investments [Policy Text Block]	Cash Equivalents and Restricted Cash and Investments Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other current assets and investments and restricted cash and investments on the Consolidated Balance Sheets.
Investments [Policy Text Block]	Investments The Company's management determines the appropriate classification of investments in debt and equity securities at the acquisition date and reevaluates the classification at each balance sheet date. Investments and restricted cash and investments that management does not intend to use or is restricted from using in current operations are presented as noncurrent on the Consolidated Balance Sheets. Available-for-sale securities are carried at fair value with realized gains and losses, as determined on a specific identification basis, recognized in earnings and unrealized gains and losses recognized in AOCI, net of tax. Realized and unrealized gains and losses on securities in a trust related to the decommissioning of nuclear generation assets are recorded as a net regulatory liability since the Company expects to recover costs for these activities through regulated rates. Trading securities are carried at fair value with realized and unrealized gains and losses recognized in earnings. Held-to-maturity securities are carried at amortized cost, reflecting the ability and intent to hold the securities to maturity. The Company utilizes the equity method of accounting with respect to investments when it possesses the ability to exercise significant influence, but not control, over the operating and financial policies of the investee. The ability to exercise significant influence is presumed when an investor possesses more than 20% of the voting interests of the investee. This presumption may be overcome based on specific facts and circumstances that demonstrate the ability to exercise significant influence is restricted. In applying the equity method, the Company records the investment at cost and subsequently increases or decreases the carrying value of the investment by the Company's proportionate share of the net earnings or losses and other comprehensive income (loss) ("OCI") of the investee. The Company records dividends or other equity distributions as reductions in the carrying value of the investment. Certain equity investments are presented on the Consolidated Balance Sheets net of related investment tax credits. Investments gains and losses arise when investments are sold (as determined on a specific identification basis) or are other-than-temporarily impaired. If a decline in value of an investment below cost is deemed other than temporary, the cost of the investment is written down to fair value, with a corresponding charge to earnings. Factors considered in judging whether an impairment is other than temporary include: the financial condition, business prospects and creditworthiness of the issuer; the relative amount of the decline; the Company's ability and intent to hold the investment until the fair value recovers; and the length of time that fair value has been less than cost. Impairment losses on equity securities are charged to earnings. With respect to an investment in a debt security, any resulting impairment loss is recognized in earnings if the Company intends to sell, or expects to be required to sell, the debt security before its amortized cost is recovered. If the Company does not expect to ultimately recover the amortized cost basis even if it does not intend to sell the security, the credit loss component is recognized in earnings and any difference between fair value and the amortized cost basis, net of the credit loss, is reflected in OCI. For regulated investments, any impairment charge is offset by the establishment of a regulatory asset to the extent recovery in regulated rates is probable.
Allowance for doubtful accounts [Policy Text Block]	Allowance for Doubtful Accounts Trade receivables are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on the Company's assessment of the collectibility of amounts owed to the Company by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. As of December 31, 2016 and 2015 , the allowance for doubtful accounts totaled $33 million and $31 million , respectively, and is included in trade receivables, net on the Consolidated Balance Sheets.
Derivatives [Policy Text Block]	Derivatives The Company employs a number of different derivative contracts, which may include forwards, futures, options, swaps and other agreements, to manage its commodity price, interest rate, and foreign currency exchange rate risk. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Cash collateral received from or paid to counterparties to secure derivative contract assets or liabilities in excess of amounts offset is included in other current assets on the Consolidated Balance Sheets. Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked-to-market and settled amounts are recognized as operating revenue or cost of sales on the Consolidated Statements of Operations. For the Company's derivatives not designated as hedging contracts, the settled amount is generally included in regulated rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in regulated rates are recorded as regulatory assets and liabilities. For the Company's derivatives not designated as hedging contracts and for which changes in fair value are not recorded as regulatory assets and liabilities, unrealized gains and losses are recognized on the Consolidated Statements of Operations as operating revenue for sales contracts; cost of sales and operating expense for purchase contracts and electricity, natural gas and fuel swap contracts; and other, net for interest rate swap derivatives. For the Company's derivatives designated as hedging contracts, the Company formally assesses, at inception and thereafter, whether the hedging contract is highly effective in offsetting changes in the hedged item. The Company formally documents hedging activity by transaction type and risk management strategy. Changes in the estimated fair value of a derivative contract designated and qualified as a cash flow hedge, to the extent effective, are included on the Consolidated Statements of Changes in Equity as AOCI, net of tax, until the contract settles and the hedged item is recognized in earnings. The Company discontinues hedge accounting prospectively when it has determined that a derivative contract no longer qualifies as an effective hedge, or when it is no longer probable that the hedged forecasted transaction will occur. When hedge accounting is discontinued because the derivative contract no longer qualifies as an effective hedge, future changes in the estimated fair value of the derivative contract are charged to earnings. Gains and losses related to discontinued hedges that were previously recorded in AOCI will remain in AOCI until the contract settles and the hedged item is recognized in earnings, unless it becomes probable that the hedged forecasted transaction will not occur at which time associated deferred amounts in AOCI are immediately recognized in earnings.
Inventories [Policy Text Block]	Inventories Inventories consist mainly of fuel, which includes coal stocks, stored gas and fuel oil, totaling $402 million and $353 million as of December 31, 2016 and 2015 , respectively, and materials and supplies totaling $523 million and $529 million as of December 31, 2016 and 2015 , respectively. The cost of materials and supplies, coal stocks and fuel oil is determined primarily using the average cost method. The cost of stored gas is determined using either the last-in-first-out ("LIFO") method or the lower of average cost or market. With respect to inventories carried at LIFO cost, the replacement cost would be $27 million and $8 million higher as of December 31, 2016 and 2015 , respectively.
Property, plant and equipment, net - general [Policy Text Block]	Property, Plant and Equipment, Net General Additions to property, plant and equipment are recorded at cost. The Company capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs. Indirect construction costs include capitalized interest, including debt allowance for funds used during construction ("AFUDC"), and equity AFUDC, as applicable to the Regulated Businesses. The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. Additionally, MidAmerican Energy has regulatory arrangements in Iowa in which the carrying cost of certain utility plant has been reduced for amounts associated with electric returns on equity exceeding specified thresholds. Depreciation and amortization are generally computed by applying the composite or straight-line method based on either estimated useful lives or mandated recovery periods as prescribed by the Company's various regulatory authorities. Depreciation studies are completed by the Regulated Businesses to determine the appropriate group lives, net salvage and group depreciation rates. These studies are reviewed and rates are ultimately approved by the applicable regulatory commission. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as either a cost of removal regulatory liability or an ARO liability on the Consolidated Balance Sheets, depending on whether the obligation meets the requirements of an ARO. As actual removal costs are incurred, the associated liability is reduced. Generally when the Company retires or sells a component of regulated property, plant and equipment, it charges the original cost, net of any proceeds from the disposition, to accumulated depreciation. Any gain or loss on disposals of all other assets is recorded through earnings. Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of regulated facilities, is capitalized by the Regulated Businesses as a component of property, plant and equipment, with offsetting credits to the Consolidated Statements of Operations. AFUDC is computed based on guidelines set forth by the Federal Energy Regulatory Commission ("FERC") and the Alberta Utilities Commission ("AUC"). After construction is completed, the Company is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets.
Property, plant and equipment, net - asset retirement obligations [Policy Text Block]	Asset Retirement Obligations The Company recognizes AROs when it has a legal obligation to perform decommissioning, reclamation or removal activities upon retirement of an asset. The Company's AROs are primarily related to the decommissioning of nuclear generating facilities and obligations associated with its other generating facilities and offshore natural gas pipelines. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to property, plant and equipment, net) and for accretion of the ARO liability due to the passage of time. For the Regulated Businesses, the difference between the ARO liability, the corresponding ARO asset included in property, plant and equipment, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability.
Property, plant and equipment, net - impairment [Policy Text Block]	Impairment The Company evaluates long-lived assets for impairment, including property, plant and equipment, when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable or the assets are being held for sale. Upon the occurrence of a triggering event, the asset is reviewed to assess whether the estimated undiscounted cash flows expected from the use of the asset plus the residual value from the ultimate disposal exceeds the carrying value of the asset. If the carrying value exceeds the estimated recoverable amounts, the asset is written down to the estimated fair value and any resulting impairment loss is reflected on the Consolidated Statements of Operations. The impacts of regulation are considered when evaluating the carrying value of regulated assets.
Goodwill [Policy Text Block]	Goodwill Goodwill represents the excess of the purchase price over the fair value of identifiable net assets acquired in business combinations. The Company evaluates goodwill for impairment at least annually and completed its annual review as of October 31. When evaluating goodwill for impairment, the Company estimates the fair value of the reporting unit. If the carrying amount of a reporting unit, including goodwill, exceeds the estimated fair value, then the identifiable assets, including identifiable intangible assets, and liabilities of the reporting unit are estimated at fair value as of the current testing date. The excess of the estimated fair value of the reporting unit over the current estimated fair value of net assets establishes the implied value of goodwill. The excess of the recorded goodwill over the implied goodwill value is charged to earnings as an impairment loss. Significant judgment is required in estimating the fair value of the reporting unit and performing goodwill impairment tests. The Company uses a variety of methods to estimate a reporting unit's fair value, principally discounted projected future net cash flows. Key assumptions used include, but are not limited to, the use of estimated future cash flows; multiples of earnings; and an appropriate discount rate. In estimating future cash flows, the Company incorporates current market information, as well as historical factors. As such, the determination of fair value incorporates significant unobservable inputs. During 2016 , 2015 and 2014 , the Company did not record any goodwill impairments. The Company records goodwill adjustments for (a) the tax benefit associated with the excess of tax-deductible goodwill over the reported amount of goodwill and (b) changes to the purchase price allocation prior to the end of the measurement period, which is not to exceed one year from the acquisition date.
Revenue recognition [Policy Text Block]	Revenue Recognition Energy Businesses Revenue from energy business customers is recognized as electricity or natural gas is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31, 2016 and 2015 , unbilled revenue was $643 million and $660 million , respectively, and is included in trade receivables, net on the Consolidated Balance Sheets. Rates for energy businesses are established by regulators or contractual arrangements. When preliminary regulated rates are permitted to be billed prior to final approval by the applicable regulator, certain revenue collected may be subject to refund and a liability for estimated refunds is accrued. The Company records sales, franchise and excise taxes collected directly from customers and remitted directly to the taxing authorities on a net basis on the Consolidated Statements of Operations. Real Estate Commission Revenue, Mortgage Revenue and Franchise Royalty Fees Commission revenue from real estate brokerage transactions and related amounts due to agents are recognized when a real estate transaction is closed. Title and escrow closing fee revenue from real estate transactions and related amounts due to the title insurer are recognized at closing. Mortgage fee revenue consists of amounts earned related to application and underwriting fees, and fees on canceled loans. Fees associated with the origination and acquisition of mortgage loans are recognized as earned. Franchise royalty fees are based on a percentage of commissions earned by franchisees on real estate sales and are recognized when the sale closes.
Unamortized debt premiums, discounts and financing costs [Policy Text Block]	Unamortized Debt Premiums, Discounts and Debt Issuance Costs Premiums, discounts and debt issuance costs incurred for the issuance of long-term debt are amortized over the term of the related financing using the effective interest method.
Foreign currency [Policy Text Block]	Foreign Currency The accounts of foreign-based subsidiaries are measured in most instances using the local currency of the subsidiary as the functional currency. Revenue and expenses of these businesses are translated into United States dollars at the average exchange rate for the period. Assets and liabilities are translated at the exchange rate as of the end of the reporting period. Gains or losses from translating the financial statements of foreign-based operations are included in equity as a component of AOCI. Gains or losses arising from transactions denominated in a currency other than the functional currency of the entity that is party to the transaction are included in earnings.
Income taxes [Policy Text Block]	Income Taxes Berkshire Hathaway includes the Company in its United States federal income tax return. The Company's provision for income taxes has been computed on a stand-alone basis. Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of OCI are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with income tax benefits and expense for certain property-related basis differences and other various differences that PacifiCorp, MidAmerican Energy, Nevada Power and Sierra Pacific (the "Utilities") are required to pass on to their customers in most state jurisdictions are charged or credited directly to a regulatory asset or liability. As of December 31, 2016 and 2015 , these amounts were recognized as regulatory assets of $1.6 billion and $1.5 billion , respectively, and regulatory liabilities of $25 million and $29 million , respectively, and will be included in regulated rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Valuation allowances are established when necessary to reduce deferred income tax assets to the amount that is more-likely-than-not to be realized. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties or as prescribed by various regulatory jurisdictions.
Unremitted earnings in foreign investment [Policy Text Block]	The Company has not established deferred income taxes on the undistributed foreign earnings of Northern Powergrid or AltaLink or the related currency translation adjustment that have been determined by management to be reinvested indefinitely. The cumulative undistributed foreign earnings were approximately $3.0 billion as of December 31, 2016 . The Company periodically evaluates its capital requirements. If circumstances change in the future and a portion of Northern Powergrid's or AltaLink's undistributed earnings were repatriated, the dividends would be subject to taxation in the United States. However, any United States income tax liability would be offset, in part, by available United States income tax credits with respect to corporate income taxes previously paid in the United Kingdom and Canada. Because of the availability of foreign income tax credits, it is not practicable to determine the United States income tax liability that would be recognized if such cumulative earnings were not reinvested indefinitely. The Company has established deferred income taxes on all other undistributed foreign earnings. If opportunities become available to repatriate any available cash without triggering incremental United States income tax expense, the Company may distribute certain foreign earnings of Northern Powergrid and AltaLink.
Income tax uncertainties [Policy Text Block]	In determining the Company's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by the Company's various regulatory jurisdictions. The Company's income tax returns are subject to continuous examinations by federal, state, local and foreign income tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. The Company recognizes the tax benefit from an uncertain tax position only if it is more-likely-than-not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Consolidated Financial Statements from such a position are measured based on the largest benefit that is more-likely-than-not to be realized upon ultimate settlement. Although the ultimate resolution of the Company's federal, state, local and foreign income tax examinations is uncertain, the Company believes it has made adequate provisions for these income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on the Company's consolidated financial results. The Company's unrecognized tax benefits are primarily included in accrued property, income and other taxes and other long-term liabilities on the Consolidated Balance Sheets. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Consolidated Statements of Operations.
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. The material impacts currently identified include recording the unrealized gains and losses on available-for-sale securities in the Consolidated Statements of Operations as opposed to OCI. For the years ended December 31, 2016, 2015 and 2014, these amounts, net of tax, were $(30) million , $225 million and $(134) million , respectively. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. The Company currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized when the Company has the right to invoice as it corresponds directly with the value to the customer of the Company’s performance to date. The Company's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by regulated energy, nonregulated energy and real estate, with further disaggregation of regulated energy by jurisdiction and real estate by line of business. In January 2014, the FASB issued ASU No. 2014-05, which amends FASB ASC Topic 853, "Service Concession Arrangements" ("ASC 853"). The amendments in this guidance require an entity to not account for service concession arrangements as a lease and should also not recognize them as property, plant and equipment. This guidance is effective for interim and annual reporting periods beginning after December 15, 2014. The Company adopted this guidance effective January 1, 2015 under a modified retrospective method where the cumulative effect is recognized at the date of initial application. The adoption resulted in the establishment of a financial asset with a related recognition of interest income, the elimination of a portion of previously recognized property, plant and equipment, the elimination of recognizing guaranteed water and energy delivery fees in operating revenue and increases to retained earnings attributable to the Company of $56 million and noncontrolling interests of $11 million . New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. Sierra Pacific currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what Sierra Pacific has the right to invoice as it corresponds directly with the value to the customer of Sierra Pacific’s performance to date. Sierra Pacific's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by segment and customer class.
PacifiCorp [Member]
Allowance for Doubtful Accounts [Line Items]
Basis of consolidation and presentation [Policy Text Block]	Basis of Consolidation and Presentation The Consolidated Financial Statements include the accounts of PacifiCorp and its subsidiaries in which it holds a controlling financial interest as of the financial statement date. Intercompany accounts and transactions have been eliminated.
Use of estimates in preparation of financial statements [Policy Text Block]	Use of Estimates in Preparation of Financial Statements The preparation of the Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Consolidated Financial Statements.
Accounting for the effects of certain types of regulation [Policy Text Block]	Accounting for the Effects of Certain Types of Regulation PacifiCorp prepares its financial statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, PacifiCorp defers the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in rates occur. PacifiCorp continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition that could limit PacifiCorp's ability to recover its costs. PacifiCorp believes the application of the guidance for regulated operations is appropriate and its existing regulatory assets and liabilities are probable of inclusion in future rates. The evaluation reflects the current political and regulatory climate at both the federal and state levels. If it becomes no longer probable that the deferred costs or income will be included in future rates, the related regulatory assets and liabilities will be written off to net income or re-established as accumulated other comprehensive income (loss) ("AOCI").
Fair value measurement [Policy Text Block]	Fair Value Measurements As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange.
Cash equivalent and restricted cash and investments [Policy Text Block]	Cash Equivalents and Restricted Cash and Investments Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other current assets and other assets on the Consolidated Balance Sheets.
Investments [Policy Text Block]	Investments Available-for-sale securities are carried at fair value with realized gains and losses, as determined on a specific identification basis, recognized in earnings and unrealized gains and losses recognized in AOCI, net of tax. As of December 31, 2016 and 2015 , PacifiCorp had no unrealized gains and losses on available-for-sale securities. Trading securities are carried at fair value with realized and unrealized gains and losses recognized in earnings. PacifiCorp utilizes the equity method of accounting with respect to investments when it possesses the ability to exercise significant influence, but not control, over the operating and financial policies of the investee. The ability to exercise significant influence is presumed when an investor possesses more than 20% of the voting interests of the investee. This presumption may be overcome based on specific facts and circumstances that demonstrate the ability to exercise significant influence is restricted. In applying the equity method, PacifiCorp records the investment at cost and subsequently increases or decreases the carrying value of the investment by PacifiCorp's proportionate share of the net earnings or losses and other comprehensive income (loss) ("OCI") of the investee. PacifiCorp records dividends or other equity distributions as reductions in the carrying value of the investment.
Allowance for doubtful accounts [Policy Text Block]	Allowance for Doubtful Accounts Accounts receivable are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on PacifiCorp's assessment of the collectibility of amounts owed to PacifiCorp by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. The change in the balance of the allowance for doubtful accounts, which is included in accounts receivable, net on the Consolidated Balance Sheets, is summarized as follows for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 7 $ 7 $ 8 Charged to operating costs and expenses, net 12 10 11 Write-offs, net (12 ) (10 ) (12 ) Ending balance $ 7 $ 7 $ 7
Derivatives [Policy Text Block]	Derivatives PacifiCorp employs a number of different derivative contracts, which may include forwards, options, swaps and other agreements, to manage price risk for electricity, natural gas and other commodities and interest rate risk. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked-to-market and settled amounts are recognized as operating revenue or energy costs on the Consolidated Statements of Operations. For PacifiCorp's derivative contracts, the settled amount is generally included in rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in rates are recorded as regulatory liabilities or assets. For a derivative contract not probable of inclusion in rates, changes in the fair value are recognized in earnings.
Inventories [Policy Text Block]	Inventories Inventories consist of materials and supplies, coal stocks, natural gas and fuel oil, which are stated at the lower of average cost or net realizable value.
Property, plant and equipment, net - general [Policy Text Block]	Property, Plant and Equipment, Net General Additions to property, plant and equipment are recorded at cost. PacifiCorp capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs, which include debt and equity allowance for funds used during construction ("AFUDC"). The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. Depreciation and amortization are generally computed on the straight-line method based on composite asset class lives prescribed by PacifiCorp's various regulatory authorities or over the assets' estimated useful lives. Depreciation studies are completed periodically to determine the appropriate composite asset class lives, net salvage and depreciation rates. These studies are reviewed and rates are ultimately approved by the various regulatory authorities. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as either a cost of removal regulatory liability or an ARO liability on the Consolidated Balance Sheets, depending on whether the obligation meets the requirements of an ARO. As actual removal costs are incurred, the associated liability is reduced. Generally when PacifiCorp retires or sells a component of regulated property, plant and equipment, it charges the original cost, net of any proceeds from the disposition, to accumulated depreciation. Any gain or loss on disposals of all other assets is recorded through earnings. Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of property, plant and equipment, is capitalized as a component of property, plant and equipment, with offsetting credits to the Consolidated Statements of Operations. AFUDC is computed based on guidelines set forth by the Federal Energy Regulatory Commission ("FERC"). After construction is completed, PacifiCorp is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets.
Property, plant and equipment, net - asset retirement obligations [Policy Text Block]	Asset Retirement Obligations PacifiCorp recognizes AROs when it has a legal obligation to perform decommissioning, reclamation or removal activities upon retirement of an asset. PacifiCorp's AROs are primarily associated with its generating facilities. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to property, plant and equipment, net) and for accretion of the ARO liability due to the passage of time. The difference between the ARO liability, the corresponding ARO asset included in property, plant and equipment, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability.
Revenue recognition [Policy Text Block]	Revenue Recognition Revenue is recognized as electricity is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31, 2016 and 2015 , unbilled revenue was $275 million and $245 million , respectively, and is included in accounts receivable, net on the Consolidated Balance Sheets. Rates charged are established by regulators or contractual arrangements. The determination of sales to individual customers is based on the reading of the customer's meter, which is performed on a systematic basis throughout the month. At the end of each month, energy provided to customers since the date of the last meter reading is estimated, and the corresponding unbilled revenue is recorded. The estimate is reversed in the following month and actual revenue is recorded based on subsequent meter readings. The monthly unbilled revenues of PacifiCorp are determined by the estimation of unbilled energy provided during the period, the assignment of unbilled energy provided to customer classes and the average rate per customer class. Factors that can impact the estimate of unbilled energy include, but are not limited to, seasonal weather patterns, total volumes supplied to the system, line losses, economic impacts and composition of sales among customer classes. PacifiCorp records sales, franchise and excise taxes collected directly from customers and remitted directly to the taxing authorities on a net basis on the Consolidated Statements of Operations.
Income taxes [Policy Text Block]	Income Taxes Berkshire Hathaway includes PacifiCorp in its United States federal income tax return. Consistent with established regulatory practice, PacifiCorp's provision for income taxes has been computed on a stand-alone basis. Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of OCI are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with income tax benefits and expense for certain property-related basis differences and other various differences that PacifiCorp is required to pass on to its customers are charged or credited directly to a regulatory asset or liability. These amounts were recognized as regulatory assets of $421 million and $437 million as of December 31, 2016 and 2015 , respectively, and regulatory liabilities of $9 million and $12 million as of December 31, 2016 and 2015 , respectively, and will be included in rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Valuation allowances are established when necessary to reduce deferred income tax assets to the amount that is more likely than not to be realized. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties or as prescribed by various regulatory jurisdictions. Investment tax credits are included in other long-term liabilities on the Consolidated Balance Sheets and were $18 million and $23 million as of December 31, 2016 and 2015 , respectively.
Income tax uncertainties [Policy Text Block]	In determining PacifiCorp's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by PacifiCorp's various regulatory jurisdictions. PacifiCorp's income tax returns are subject to continuous examinations by federal, state and local income tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. PacifiCorp recognizes the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Consolidated Financial Statements from such a position are measured based on the largest benefit that is more likely than not to be realized upon ultimate settlement. Although the ultimate resolution of PacifiCorp's federal, state and local income tax examinations is uncertain, PacifiCorp believes it has made adequate provisions for these income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on PacifiCorp's consolidated financial results. PacifiCorp's unrecognized tax benefits are primarily included in other long-term liabilities on the Consolidated Balance Sheets. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Consolidated Statements of Operations.
Segment reporting	Segment Information PacifiCorp currently has one segment, which includes its regulated electric utility operations.
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. The impact of this update is immaterial to PacifiCorp's Consolidated Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. PacifiCorp currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what PacifiCorp has the right to invoice as it corresponds directly with the value to the customer of PacifiCorp’s performance to date. PacifiCorp’s current plan is to quantitatively disaggregate revenue in the required financial statement footnote by customer class and jurisdiction.
MidAmerican Energy Company [Member]
Allowance for Doubtful Accounts [Line Items]
Use of estimates in preparation of financial statements [Policy Text Block]	Use of Estimates in Preparation of Financial Statements The preparation of the Financial Statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Financial Statements.
Accounting for the effects of certain types of regulation [Policy Text Block]	A ccounting for the Effects of Certain Types of Regulation MidAmerican Energy's utility operations are subject to the regulation of the Iowa Utilities Board ("IUB"), the Illinois Commerce Commission ("ICC"), the South Dakota Public Utilities Commission, and the Federal Energy Regulatory Commission ("FERC"). MidAmerican Energy's accounting policies and the accompanying Financial Statements conform to GAAP applicable to rate-regulated enterprises and reflect the effects of the ratemaking process. MidAmerican Energy prepares its financial statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, MidAmerican Energy defers the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future regulated rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in regulated rates occur. MidAmerican Energy continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future regulated rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition, that could limit MidAmerican Energy's ability to recover its costs. MidAmerican Energy believes the application of the guidance for regulated operations is appropriate, and its existing regulatory assets and liabilities are probable of inclusion in future regulated rates. The evaluation reflects the current political and regulatory climate at both the federal and state levels. If it becomes no longer probable that the deferred costs or income will be included in future regulated rates, the related regulatory assets and liabilities will be written off to net income, returned to customers or re-established as accumulated other comprehensive income (loss) ("AOCI").
Fair value measurement [Policy Text Block]	Fair Value Measurements As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange.
Cash equivalent and restricted cash and investments [Policy Text Block]	Cash Equivalents and Restricted Cash and Investments Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other current assets and restricted cash and investments on the Balance Sheets.
Investments [Policy Text Block]	Investments MidAmerican Energy's management determines the appropriate classification of investments in debt and equity securities at the acquisition date and reevaluates the classification at each balance sheet date. Investments that management does not intend to use or is restricted from using in current operations are presented as noncurrent on the Balance Sheets. Available-for-sale securities are carried at fair value with realized gains and losses, as determined on a specific identification basis, recognized in earnings and unrealized gains and losses recognized in AOCI, net of tax. Realized and unrealized gains and losses on securities in a trust related to the decommissioning of the Quad Cities Generating Station Units 1 and 2 ("Quad Cities Station") are recorded as a net regulatory liability because MidAmerican Energy expects to recover costs for these activities through regulated rates. Held-to-maturity securities are carried at amortized cost, reflecting the ability and intent to hold the securities to maturity. Investments gains and losses arise when investments are sold (as determined on a specific identification basis) or are other-than-temporarily impaired. If a decline in value of an investment below cost is deemed other than temporary, the cost of the investment is written down to fair value, with a corresponding charge to earnings. Factors considered in judging whether an impairment is other than temporary include: the financial condition, business prospects and creditworthiness of the issuer; the relative amount of the decline; MidAmerican Energy's ability and intent to hold the investment until the fair value recovers; and the length of time that fair value has been less than cost. Impairment losses on equity securities are charged to earnings. With respect to an investment in a debt security, any resulting impairment loss is recognized in earnings if MidAmerican Energy intends to sell, or expects to be required to sell, the debt security before its amortized cost is recovered. If MidAmerican Energy does not expect to ultimately recover the amortized cost basis even if it does not intend to sell the security, the credit loss component is recognized in earnings and any difference between fair value and the amortized cost basis, net of the credit loss, is reflected in other comprehensive income (loss) ("OCI"). For regulated investments, any impairment charge is offset by the establishment of a regulatory asset to the extent recovery in regulated rates is probable.
Allowance for doubtful accounts [Policy Text Block]	Allowance for Doubtful Accounts Receivables are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on MidAmerican Energy's assessment of the collectibility of amounts owed to it by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. As of December 31, 2016 and 2015 , the allowance for doubtful accounts totaled $7 million and $6 million , respectively, and is included in receivables, net on the Balance Sheets.
Derivatives [Policy Text Block]	Derivatives MidAmerican Energy employs a number of different derivative contracts, including forwards, futures, options, swaps and other agreements, to manage price risk for electricity, natural gas and other commodities, and interest rate risk. Derivative contracts are recorded on the Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Cash collateral received from or paid to counterparties to secure derivative contract assets or liabilities in excess of amounts offset is included in other current assets on the Balance Sheets. Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked to market, and settled amounts are recognized as operating revenue or cost of sales on the Statements of Operations. For MidAmerican Energy's derivatives not designated as hedging contracts, the settled amount is generally included in regulated rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in regulated rates are recorded as regulatory assets and liabilities. For MidAmerican Energy's derivatives designated as hedging contracts, MidAmerican Energy formally assesses, at inception and thereafter, whether the hedging contract is highly effective in offsetting changes in the hedged item. MidAmerican Energy formally documents hedging activity by transaction type and risk management strategy. Changes in the estimated fair value of a derivative contract designated and qualified as a cash flow hedge, to the extent effective, are included on the Statements of Changes in Equity as AOCI, net of tax, until the contract settles and the hedged item is recognized in earnings. All of MidAmerican Energy's derivatives designated as cash flow hedges and the related AOCI were transferred to a subsidiary of BHE on January 1, 2016, as discussed in Note 3 .
Inventories [Policy Text Block]	Inventories Inventories consist mainly of coal stocks, totaling $137 million and $102 million as of December 31, 2016 and 2015 , respectively, materials and supplies, totaling $99 million and $105 million as of December 31, 2016 and 2015 , respectively, and natural gas in storage, totaling $24 million and $27 million as of December 31, 2016 and 2015 , respectively. The cost of materials and supplies, coal stocks and fuel oil is determined using the average cost method. The cost of stored natural gas is determined using the last-in-first-out method. With respect to stored natural gas, the replacement cost would be $27 million and $8 million higher as of December 31, 2016 and 2015 , respectively.
Property, plant and equipment, net - general [Policy Text Block]	Utility Plant, Net General Additions to utility plant are recorded at cost. MidAmerican Energy capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs. Indirect construction costs include debt allowance for funds used during construction ("AFUDC") and equity AFUDC. The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. Additionally, MidAmerican Energy has regulatory arrangements in Iowa in which the carrying cost of certain utility plant has been reduced for amounts associated with electric returns on equity exceeding specified thresholds. Amounts expensed under this arrangement are included as a component of depreciation and amortization. Depreciation and amortization for MidAmerican Energy's utility operations are computed by applying the composite or straight-line method based on either estimated useful lives or mandated recovery periods as prescribed by its various regulatory authorities. Depreciation studies are completed by MidAmerican Energy to determine the appropriate group lives, net salvage and group depreciation rates. These studies are reviewed and rates are ultimately approved by the applicable regulatory commission. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as either a cost of removal regulatory liability or an ARO liability on the Balance Sheets, depending on whether the obligation meets the requirements of an ARO. As actual removal costs are incurred, the associated liability is reduced. Generally, when MidAmerican Energy retires or sells a component of utility plant, it charges the original cost, net of any proceeds from the disposition to accumulated depreciation. Any gain or loss on disposals of nonregulated assets is recorded through earnings. Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of its regulated facilities, is capitalized by MidAmerican Energy as a component of utility plant, with offsetting credits to the Statements of Operations. AFUDC is computed based on guidelines set forth by the FERC. After construction is completed, MidAmerican Energy is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets.
Property, plant and equipment, net - asset retirement obligations [Policy Text Block]	Asset Retirement Obligations MidAmerican Energy recognizes AROs when it has a legal obligation to perform decommissioning or removal activities upon retirement of an asset. MidAmerican Energy's AROs are primarily related to decommissioning of the Quad Cities Station and obligations associated with its other generating facilities. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to utility plant) and for accretion of the ARO liability due to the passage of time. The difference between the ARO liability, the corresponding ARO asset included in utility plant, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability.
Property, plant and equipment, net - impairment [Policy Text Block]	Impairment MidAmerican Energy evaluates long-lived assets for impairment, including utility plant, when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable or the assets are being held for sale. Upon the occurrence of a triggering event, the asset is reviewed to assess whether the estimated undiscounted cash flows expected from the use of the asset plus the residual value from the ultimate disposal exceeds the carrying value of the asset. If the carrying value exceeds the estimated recoverable amounts, the asset is written down to the estimated fair value. The impacts of regulation are considered when evaluating the carrying value of regulated assets. For all other assets, any resulting impairment loss is reflected on the Statements of Operations.
Revenue recognition [Policy Text Block]	Revenue Recognition Revenue from electric and natural gas customers is recognized as electricity or natural gas is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31, 2016 and 2015 , unbilled revenue was $87 million and $138 million , respectively, and is included in receivables, net on the Balance Sheets. The determination of customer billings is based on a systematic reading of customer meters and applicable rates. At the end of each month, amounts of energy provided to customers since the date of the last meter reading are estimated, and the corresponding unbilled revenue is recorded. Factors that can impact the estimate of unbilled energy include, but are not limited to, seasonal weather patterns, total volumes supplied to the system, line losses, economic impacts and composition of customer classes. Unbilled revenue is reversed in the following month and billed revenue is recorded based on the subsequent meter readings. All of MidAmerican Energy's regulated retail electric and gas sales are subject to energy adjustment clauses. MidAmerican Energy also has costs that are recovered, at least in part, through bill riders, including demand-side management and certain transmission costs. The clauses and riders allow MidAmerican Energy to adjust the amounts charged for electric and gas service as the related costs change. The costs recovered in revenue through use of the adjustment clauses and bill riders are charged to expense in the same year the related revenue is recognized. At any given time, these costs may be over or under collected from customers. The total under collection included in receivables at December 31, 2016 and 2015 , was $31 million and $17 million , respectively. MidAmerican Energy collects from its customers sales and excise taxes assessed by governmental authorities on transactions with customers and later remits the collected taxes to the appropriate authority. If the obligation to pay a particular tax resides with the customer, MidAmerican Energy reports such taxes collected on a net basis and, accordingly, they do not affect the Statement of Operations. Taxes for which the obligation resides with MidAmerican Energy are reported on a gross basis in operating revenue and operating expenses. The amounts reported on a gross basis are not material.
Unamortized debt premiums, discounts and financing costs [Policy Text Block]	Unamortized Debt Premiums, Discounts and Issuance Costs Premiums, discounts and issuance costs incurred for the issuance of long-term debt are amortized over the term of the related financing using the effective interest method.
Income taxes [Policy Text Block]	Income Taxes Berkshire Hathaway includes MidAmerican Funding and MidAmerican Energy in its United States federal income tax return. MidAmerican Funding's and MidAmerican Energy's provisions for income taxes have been computed on a stand-alone basis. Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of OCI are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with income tax benefits and expense for certain property-related basis differences and other various differences that MidAmerican Energy is required to pass on to its customers in Iowa are charged or credited directly to a regulatory asset or liability. As of December 31, 2016 and 2015 , these amounts were recognized as a net regulatory asset totaling $985 million and $858 million , respectively, and will be included in regulated rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties or as prescribed by various regulatory jurisdictions.
Income tax uncertainties [Policy Text Block]	In determining MidAmerican Funding's and MidAmerican Energy's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by MidAmerican Energy's various regulatory jurisdictions. MidAmerican Funding's and MidAmerican Energy's income tax returns are subject to continuous examinations by federal, state and local tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. MidAmerican Funding and MidAmerican Energy recognize the tax benefit from an uncertain tax position only if it is more-likely-than-not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Consolidated Financial Statements from such a position are measured based on the largest benefit that is more-likely-than-not to be realized upon ultimate settlement. Although the ultimate resolution of their federal, state and local income tax examinations is uncertain, each company believes it has made adequate provisions for its income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on its consolidated financial results. MidAmerican Funding's and MidAmerican Energy's unrecognized tax benefits are primarily included in taxes accrued and other long-term liabilities on their respective Consolidated Balance Sheets. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Consolidated Statements of Operations.
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively, wherein the statement of cash flows of each period presented should be adjusted to reflect the new guidance. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No.2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. MidAmerican Energy currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what MidAmerican Energy has the right to invoice as it corresponds directly with the value to the customer of MidAmerican Energy’s performance to date. MidAmerican Energy's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by jurisdiction for each segment.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Allowance for Doubtful Accounts [Line Items]
Basis of consolidation and presentation [Policy Text Block]	Basis of Consolidation and Presentation The Consolidated Financial Statements include the accounts of MidAmerican Funding and its subsidiaries in which it held a controlling financial interest as of the financial statement date. Intercompany accounts and transactions have been eliminated, other than those between rate-regulated operations.
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	Goodwill Goodwill represents the excess of the purchase price over the fair value of identifiable net assets acquired when MidAmerican Funding purchased MHC. MidAmerican Funding evaluates goodwill for impairment at least annually and completed its annual review as of October 31. When evaluating goodwill for impairment, MidAmerican Funding estimates the fair value of the reporting unit. If the carrying amount of a reporting unit, including goodwill, exceeds the estimated fair value, then the identifiable assets, including identifiable intangible assets, and liabilities of the reporting unit are estimated at fair value as of the current testing date. The excess of the estimated fair value of the reporting unit over the current estimated fair value of net assets establishes the implied value of goodwill. The excess of the recorded goodwill over the implied goodwill value is charged to earnings as an impairment loss. Significant judgment is required in estimating the fair value of the reporting unit and performing goodwill impairment tests. MidAmerican Funding uses a variety of methods to estimate a reporting unit's fair value, principally discounted projected future net cash flows. Key assumptions used include, but are not limited to, the use of estimated future cash flows; multiples of earnings; and an appropriate discount rate. In estimating future cash flows, MidAmerican Funding incorporates current market information, as well as historical factors. As such, the determination of fair value incorporates significant unobservable inputs. During 2016 , 2015 and 2014 , MidAmerican Funding did not record any goodwill impairments.
Nevada Power Company [Member]
Allowance for Doubtful Accounts [Line Items]
Basis of consolidation and presentation [Policy Text Block]	Basis of Consolidation and Presentation The Consolidated Financial Statements include the accounts of Nevada Power Company and its subsidiaries in which it holds a controlling financial interest as of the financial statement date. Intercompany accounts and transactions have been eliminated. The Consolidated Statements of Comprehensive Income have been omitted as net income equals comprehensive income for the years ended December 31, 2016 , 2015 and 2014 . Certain amounts in the prior period Consolidated Financial Statements have been reclassified to conform to the current period presentation. Such reclassifications did not impact previously reported operating income, net income or retained earnings.
Use of estimates in preparation of financial statements [Policy Text Block]	Use of Estimates in Preparation of Financial Statements The preparation of the Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; recovery of long-lived assets; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Consolidated Financial Statements.
Accounting for the effects of certain types of regulation [Policy Text Block]	Accounting for the Effects of Certain Types of Regulation Nevada Power prepares its Consolidated Financial Statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, Nevada Power defers the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future regulated rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in regulated rates occur. Nevada Power continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future regulated rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition that could limit Nevada Power 's ability to recover its costs. Nevada Power believes the application of the guidance for regulated operations is appropriate and its existing regulatory assets and liabilities are probable of inclusion in future regulated rates. The evaluation reflects the current political and regulatory climate at both the federal and state levels. If it becomes no longer probable that the deferred costs or income will be included in future regulated rates, the related regulatory assets and liabilities will be written off to net income, returned to customers or re-established as accumulated other comprehensive income (loss).
Fair value measurement [Policy Text Block]	Fair Value Measurements As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange.
Cash equivalent and restricted cash and investments [Policy Text Block]	Cash Equivalents and Restricted Cash and Investments Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other assets and other current assets on the Consolidated Balance Sheets.
Allowance for doubtful accounts [Policy Text Block]	Allowance for Doubtful Accounts Accounts receivable are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on Nevada Power 's assessment of the collectibility of amounts owed to Nevada Power by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. Nevada Power also has the ability to assess deposits on customers who have delayed payments or who are deemed to be a credit risk. The change in the balance of the allowance for doubtful accounts, which is included in accounts receivable, net on the Consolidated Balance Sheets, is summarized as follows for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 13 $ 14 $ 8 Charged to operating costs and expenses, net 16 16 14 Write-offs, net (17 ) (17 ) (8 ) Ending balance $ 12 $ 13 $ 14
Derivatives [Policy Text Block]	Derivatives Nevada Power employs a number of different derivative contracts, which may include forwards, futures, options, swaps and other agreements, to manage its commodity price and interest rate risk. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked‑to‑market and settled amounts are recognized as cost of fuel, energy and capacity on the Consolidated Statements of Operations. For Nevada Power 's derivative contracts, the settled amount is generally included in regulated rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in regulated rates are recorded as regulatory assets and liabilities. For a derivative contract not probable of inclusion in rates, changes in the fair value are recognized in earnings.
Inventories [Policy Text Block]	Inventories Inventories consist mainly of materials and supplies totaling $60 million and $58 million as of December 31 , 2016 and 2015 , respectively, and fuel, which includes coal stock, stored natural gas and fuel oil, totaling $13 million and $22 million as of December 31 , 2016 and 2015 , respectively. The cost is determined using the average cost method. Materials are charged to inventory when purchased and are expensed or capitalized to construction work in process, as appropriate, when used. Fuel costs are recovered from retail customers through the base tariff energy rates and deferred energy accounting adjustment charges approved by the Public Utilities Commission of Nevada ("PUCN").
Property, plant and equipment, net - general [Policy Text Block]	Property, Plant and Equipment, Net General Additions to property, plant and equipment are recorded at cost. Nevada Power capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs. Indirect construction costs include debt allowance for funds used during construction ("AFUDC"), and equity AFUDC, as applicable. The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. The cost of repairs and minor replacements are charged to expense when incurred with the exception of costs for generation plant maintenance under certain long-term service agreements. Costs under these agreements are expensed straight-line over the term of the agreements as approved by the PUCN. Depreciation and amortization are generally computed by applying the composite or straight-line method based on either estimated useful lives or mandated recovery periods as prescribed by Nevada Power 's various regulatory authorities. Depreciation studies are completed by Nevada Power to determine the appropriate group lives, net salvage and group depreciation rates. These studies are reviewed and rates are ultimately approved by the applicable regulatory commission. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as a non-current regulatory liability on the Consolidated Balance Sheets. As actual removal costs are incurred, the associated liability is reduced. Generally when Nevada Power retires or sells a component of regulated property, plant and equipment depreciated using the composite method, it charges the original cost, net of any proceeds from the disposition, to accumulated depreciation. Any gain or loss on disposals of all other assets is recorded through earnings with the exception of material gains or losses on regulated property, plant and equipment depreciated on a straight-line basis, which is then recorded to a regulatory asset or liability. Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of regulated facilities, are capitalized as a component of property, plant and equipment, with offsetting credits to the Consolidated Statements of Operations. The rate applied to construction costs is the lower of the PUCN allowed rate of return and rates computed based on guidelines set forth by the Federal Energy Regulatory Commission ("FERC"). After construction is completed, Nevada Power is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets. Nevada Power 's AFUDC rate used during 2016 and 2015 was 8.09% .
Property, plant and equipment, net - asset retirement obligations [Policy Text Block]	Asset Retirement Obligations Nevada Power recognizes AROs when it has a legal obligation to perform decommissioning, reclamation or removal activities upon retirement of an asset. Nevada Power 's AROs are primarily associated with its generating facilities. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to property, plant and equipment, net) and for accretion of the ARO liability due to the passage of time. The difference between the ARO liability, the corresponding ARO asset included in property, plant and equipment, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability on the Consolidated Balance Sheets. The costs are not recovered in rates until the work has been completed.
Property, plant and equipment, net - impairment [Policy Text Block]	Impairment of Long-Lived Assets Nevada Power evaluates long-lived assets for impairment, including property, plant and equipment, when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable or the assets are being held for sale. Upon the occurrence of a triggering event, the asset is reviewed to assess whether the estimated cash flows expected from the use of the asset plus the residual value from the ultimate disposal exceeds the carrying value of the asset. If the carrying value exceeds the estimated recoverable amounts, the asset is written down to the estimated fair value and any resulting impairment loss is reflected on the Consolidated Statements of Operations. As substantially all property, plant and equipment was used in regulated businesses as of December 31 , 2016 , the impacts of regulation are considered when evaluating the carrying value of regulated assets.
Revenue recognition [Policy Text Block]	Revenue Recognition Revenue is recognized as electricity is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31 , 2016 and 2015 , unbilled revenue was $91 million and $116 million , respectively, and is included in accounts receivable, net on the Consolidated Balance Sheets. Rates are established by regulators or contractual arrangements. When preliminary rates are permitted to be billed prior to final approval by the applicable regulator, certain revenue collected may be subject to refund and a liability for estimated refunds is accrued. Nevada Power records sales, franchise and excise taxes collected directly from customers and remitted directly to the taxing authorities on a net basis on the Consolidated Statements of Operations. Nevada Power primarily buys energy and natural gas to satisfy its customer load requirements. Due to changes in retail customer load requirements, Nevada Power may not take physical delivery of the energy or natural gas. Nevada Power may sell the excess energy or natural gas to the wholesale market. In such instances, it is Nevada Power 's policy to record such sales net in cost of fuel, energy and capacity.
Unamortized debt premiums, discounts and financing costs [Policy Text Block]	Unamortized Debt Premiums, Discounts and Issuance Costs Premiums, discounts and financing costs incurred for the issuance of long-term debt are amortized over the term of the related financing on a straight-line basis.
Income taxes [Policy Text Block]	Income Taxes Berkshire Hathaway includes Nevada Power in its United States federal income tax return. Consistent with established regulatory practice, Nevada Power 's provision for income taxes has been computed on a separate return basis. Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of other comprehensive income ("OCI") are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with income tax benefits and expense for certain property‑related basis differences and other various differences that Nevada Power is required to pass on to its customers are charged or credited directly to a regulatory asset or liability. As of December 31 , 2016 and 2015 , these amounts were recognized as regulatory assets of $141 million and $149 million , respectively, and regulatory liabilities of $9 million and $10 million , respectively , and will be included in regulated rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Valuation allowances are established when necessary to reduce deferred income tax assets to the amount that is more-likely-than-not to be realized. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties.
Income tax uncertainties [Policy Text Block]	In determining Nevada Power 's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by Nevada Power 's various regulatory jurisdictions. Nevada Power 's income tax returns are subject to continuous examinations by federal, state and local income tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. Nevada Power recognizes the tax benefit from an uncertain tax position only if it is more-likely-than-not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Consolidated Financial Statements from such a position are measured based on the largest benefit that is more-likely-than-not to be realized upon ultimate settlement. Although the ultimate resolution of Nevada Power 's federal, state and local income tax examinations is uncertain, Nevada Power believes it has made adequate provisions for these income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on Nevada Power 's consolidated financial results. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Consolidated Statements of Operations.
Segment reporting	Segment Information Nevada Power currently has one segment, which includes its regulated electric utility operations.
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. Nevada Power currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what Nevada Power has the right to invoice as it corresponds directly with the value to the customer of Nevada Power’s performance to date. Nevada Power's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by customer class.
Sierra Pacific Power Company [Member]
Allowance for Doubtful Accounts [Line Items]
Basis of consolidation and presentation [Policy Text Block]	Basis of Consolidation and Presentation The Consolidated Financial Statements include the accounts of Sierra Pacific and its subsidiaries in which it holds a controlling financial interest as of the financial statement date. Intercompany accounts and transactions have been eliminated. The Consolidated Statements of Comprehensive Income have been omitted as net income equals comprehensive income for the years ended December 31, 2016 , 2015 and 2014 . Certain amounts in the prior period Consolidated Financial Statements have been reclassified to conform to the current period presentation. Such reclassifications did not impact previously reported operating income, net income or retained earnings.
Use of estimates in preparation of financial statements [Policy Text Block]	Use of Estimates in Preparation of Financial Statements The preparation of the Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; recovery of long-lived assets; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Consolidated Financial Statements.
Accounting for the effects of certain types of regulation [Policy Text Block]	Accounting for the Effects of Certain Types of Regulation Sierra Pacific prepares its Consolidated Financial Statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, Sierra Pacific defers the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future regulated rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in regulated rates occur. Sierra Pacific continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future regulated rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition that could limit Sierra Pacific 's ability to recover its costs. Sierra Pacific believes the application of the guidance for regulated operations is appropriate and its existing regulatory assets and liabilities are probable of inclusion in future regulated rates. The evaluation reflects the current political and regulatory climate at both the federal and state levels. If it becomes no longer probable that the deferred costs or income will be included in future regulated rates, the related regulatory assets and liabilities will be written off to net income, returned to customers or re-established as accumulated other comprehensive income (loss).
Fair value measurement [Policy Text Block]	Fair Value Measurements As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange.
Cash equivalent and restricted cash and investments [Policy Text Block]	Cash Equivalents and Restricted Cash and Investments Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other assets and other current assets on the Consolidated Balance Sheets.
Allowance for doubtful accounts [Policy Text Block]	Allowance for Doubtful Accounts Accounts receivable are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on Sierra Pacific 's assessment of the collectibility of amounts owed to Sierra Pacific by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. Sierra Pacific also has the ability to assess deposits on customers who have delayed payments or who are deemed to be a credit risk. The change in the balance of the allowance for doubtful accounts, which is included in accounts receivable, net on the Consolidated Balance Sheets, is summarized as follows for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 1 $ 2 $ 1 Charged to operating costs and expenses, net 2 1 2 Write-offs, net (1 ) (2 ) (1 ) Ending balance $ 2 $ 1 $ 2
Derivatives [Policy Text Block]	Derivatives Sierra Pacific employs a number of different derivative contracts, which may include forwards, futures, options, swaps and other agreements, to manage its commodity price and interest rate risk. Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked‑to‑market and settled amounts are recognized as cost of fuel, energy and capacity or natural gas purchased for resale on the Consolidated Statements of Operations. For Sierra Pacific 's derivative contracts, the settled amount is generally included in regulated rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in regulated rates are recorded as regulatory assets and liabilities. For a derivative contract not probable of inclusion in rates, changes in the fair value are recognized in earnings.
Inventories [Policy Text Block]	Inventories Inventories consist mainly of materials and supplies totaling $36 million and $34 million as of December 31 , 2016 and 2015 , respectively, and fuel, which includes coal stock, stored natural gas and fuel oil, totaling $9 million and $5 million as of December 31 , 2016 and 2015 , respectively. The cost is determined using the average cost method. Materials are charged to inventory when purchased and are expensed or capitalized to construction work in process, as appropriate, when used. Fuel costs are recovered from retail customers through the base tariff energy rates and deferred energy accounting adjustment charges approved by the Public Utilities Commission of Nevada ("PUCN").
Property, plant and equipment, net - general [Policy Text Block]	Property, Plant and Equipment, Net General Additions to property, plant and equipment are recorded at cost. Sierra Pacific capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs. Indirect construction costs include debt allowance for funds used during construction ("AFUDC"), and equity AFUDC, as applicable. The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. The cost of repairs and minor replacements are charged to expense when incurred with the exception of costs for generation plant maintenance under certain long-term service agreements. Costs under these agreements are expensed straight-line over the term of the agreements as approved by the PUCN. Depreciation and amortization are generally computed by applying the composite or straight-line method based on either estimated useful lives or mandated recovery periods as prescribed by Sierra Pacific 's various regulatory authorities. Depreciation studies are completed by Sierra Pacific to determine the appropriate group lives, net salvage and group depreciation rates. These studies are reviewed and rates are ultimately approved by the applicable regulatory commission. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as a non-current regulatory liability on the Consolidated Balance Sheets. As actual removal costs are incurred, the associated liability is reduced. Generally when Sierra Pacific retires or sells a component of regulated property, plant and equipment depreciated using the composite method, it charges the original cost, net of any proceeds from the disposition, to accumulated depreciation. Any gain or loss on disposals of all other assets is recorded through earnings with the exception of material gains or losses on regulated property, plant and equipment depreciated on a straight-line basis, which is then recorded to a regulatory asset or liability. Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of regulated facilities, are capitalized as a component of property, plant and equipment, with offsetting credits to the Consolidated Statements of Operations. The rate applied to construction costs is the lower of the PUCN allowed rate of return and rates computed based on guidelines set forth by the Federal Energy Regulatory Commission ("FERC"). After construction is completed, Sierra Pacific is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets. Sierra Pacific 's AFUDC rate used during 2016 and 2015 was 7.62% for electric, 6.02% and 5.97% for natural gas, respectively, and 7.44% for common facilities.
Property, plant and equipment, net - asset retirement obligations [Policy Text Block]	Asset Retirement Obligations Sierra Pacific recognizes AROs when it has a legal obligation to perform decommissioning, reclamation or removal activities upon retirement of an asset. Sierra Pacific 's AROs are primarily associated with its generating facilities. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to property, plant and equipment, net) and for accretion of the ARO liability due to the passage of time. The difference between the ARO liability, the corresponding ARO asset included in property, plant and equipment, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability on the Consolidated Balance Sheets. The costs are not recovered in rates until the work has been completed.
Property, plant and equipment, net - impairment [Policy Text Block]	Impairment of Long-Lived Assets Sierra Pacific evaluates long-lived assets for impairment, including property, plant and equipment, when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable or the assets are being held for sale. Upon the occurrence of a triggering event, the asset is reviewed to assess whether the estimated cash flows expected from the use of the asset plus the residual value from the ultimate disposal exceeds the carrying value of the asset. If the carrying value exceeds the estimated recoverable amounts, the asset is written down to the estimated fair value and any resulting impairment loss is reflected on the Consolidated Statements of Operations. As substantially all property, plant and equipment was used in regulated businesses as of December 31 , 2016 , the impacts of regulation are considered when evaluating the carrying value of regulated assets.
Revenue recognition [Policy Text Block]	Revenue Recognition Revenue is recognized as electricity or natural gas is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31 , 2016 and 2015 , unbilled revenue was $52 million and $59 million , respectively, and is included in accounts receivable, net on the Consolidated Balance Sheets. Rates are established by regulators or contractual arrangements. When preliminary rates are permitted to be billed prior to final approval by the applicable regulator, certain revenue collected may be subject to refund and a liability for estimated refunds is accrued. Sierra Pacific records sales, franchise and excise taxes collected directly from customers and remitted directly to the taxing authorities on a net basis on the Consolidated Statements of Operations. Sierra Pacific primarily buys energy and natural gas to satisfy its customer load requirements. Due to changes in retail customer load requirements, Sierra Pacific may not take physical delivery of the energy or natural gas. Sierra Pacific may sell the excess energy or natural gas to the wholesale market. In such instances, it is Sierra Pacific 's policy to allocate the natural gas sales between generation and natural gas retail based on usage. The energy sales and natural gas sales allocated to generation are recorded net in cost of fuel, energy and capacity. The natural gas sales allocated to natural gas retail is recorded as wholesale revenue.
Unamortized debt premiums, discounts and financing costs [Policy Text Block]	Unamortized Debt Premiums, Discounts and Issuance Costs Premiums, discounts and financing costs incurred for the issuance of long-term debt are amortized over the term of the related financing on a straight-line basis.
Income taxes [Policy Text Block]	Income Taxes Berkshire Hathaway includes Sierra Pacific in its United States federal income tax return. Consistent with established regulatory practice, Sierra Pacific 's provision for income taxes has been computed on a separate return basis. Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of other comprehensive income ("OCI") are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with income tax benefits and expense for certain property-related basis differences and other various differences that Sierra Pacific is required to pass on to its customers are charged or credited directly to a regulatory asset or liability. As of December 31 , 2016 and 2015 , these amounts were recognized as regulatory assets of $85 million and $90 million , respectively, and regulatory liabilities of $6 million and $7 million , respectively , and will be included in regulated rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Valuation allowances are established when necessary to reduce deferred income tax assets to the amount that is more-likely-than-not to be realized. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties.
Income tax uncertainties [Policy Text Block]	In determining Sierra Pacific 's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by Sierra Pacific 's various regulatory jurisdictions. Sierra Pacific 's income tax returns are subject to continuous examinations by federal, state and local income tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. Sierra Pacific recognizes the tax benefit from an uncertain tax position only if it is more-likely-than-not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Consolidated Financial Statements from such a position are measured based on the largest benefit that is more-likely-than-not to be realized upon ultimate settlement. Although the ultimate resolution of Sierra Pacific 's federal, state and local income tax examinations is uncertain, Sierra Pacific believes it has made adequate provisions for these income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on Sierra Pacific 's consolidated financial results. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Consolidated Statements of Operations.

Summary of Significant Accoun43

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. The material impacts currently identified include recording the unrealized gains and losses on available-for-sale securities in the Consolidated Statements of Operations as opposed to OCI. For the years ended December 31, 2016, 2015 and 2014, these amounts, net of tax, were $(30) million , $225 million and $(134) million , respectively. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. The Company currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized when the Company has the right to invoice as it corresponds directly with the value to the customer of the Company’s performance to date. The Company's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by regulated energy, nonregulated energy and real estate, with further disaggregation of regulated energy by jurisdiction and real estate by line of business. In January 2014, the FASB issued ASU No. 2014-05, which amends FASB ASC Topic 853, "Service Concession Arrangements" ("ASC 853"). The amendments in this guidance require an entity to not account for service concession arrangements as a lease and should also not recognize them as property, plant and equipment. This guidance is effective for interim and annual reporting periods beginning after December 15, 2014. The Company adopted this guidance effective January 1, 2015 under a modified retrospective method where the cumulative effect is recognized at the date of initial application. The adoption resulted in the establishment of a financial asset with a related recognition of interest income, the elimination of a portion of previously recognized property, plant and equipment, the elimination of recognizing guaranteed water and energy delivery fees in operating revenue and increases to retained earnings attributable to the Company of $56 million and noncontrolling interests of $11 million . New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. Sierra Pacific currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what Sierra Pacific has the right to invoice as it corresponds directly with the value to the customer of Sierra Pacific’s performance to date. Sierra Pacific's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by segment and customer class.
PacifiCorp [Member]
Accounting Policies [Abstract]
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. The impact of this update is immaterial to PacifiCorp's Consolidated Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. PacifiCorp currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what PacifiCorp has the right to invoice as it corresponds directly with the value to the customer of PacifiCorp’s performance to date. PacifiCorp’s current plan is to quantitatively disaggregate revenue in the required financial statement footnote by customer class and jurisdiction.
Allowance for Doubtful Accounts [Line Items]
Public Utility Property, Plant, and Equipment (NPC, SPPC, PacifiCorp) [Table Text Block]	Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Property, plant and equipment: Generation 14 - 67 years $ 12,371 $ 12,164 Transmission 58 - 75 years 6,055 5,914 Distribution 20 - 70 years 6,590 6,408 Intangible plant (1) 5 - 62 years 884 875 Other 5 - 60 years 1,398 1,396 Property, plant and equipment in-service 27,298 26,757 Accumulated depreciation and amortization (8,793 ) (8,360 ) Net property, plant and equipment in-service 18,505 18,397 Construction work-in-progress 657 629 Total property, plant and equipment, net $ 19,162 $ 19,026 (1) Computer software costs included in intangible plant are initially assigned a depreciable life of 5 to 10 years.
Schedule of Accounts, Notes, Loans and Financing Receivable [Table Text Block]	The change in the balance of the allowance for doubtful accounts, which is included in accounts receivable, net on the Consolidated Balance Sheets, is summarized as follows for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 7 $ 7 $ 8 Charged to operating costs and expenses, net 12 10 11 Write-offs, net (12 ) (10 ) (12 ) Ending balance $ 7 $ 7 $ 7
MidAmerican Energy Company [Member]
Accounting Policies [Abstract]
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively, wherein the statement of cash flows of each period presented should be adjusted to reflect the new guidance. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No.2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements. MidAmerican Energy currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what MidAmerican Energy has the right to invoice as it corresponds directly with the value to the customer of MidAmerican Energy’s performance to date. MidAmerican Energy's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by jurisdiction for each segment.
Allowance for Doubtful Accounts [Line Items]
Public Utility Property, Plant, and Equipment (NPC, SPPC, PacifiCorp) [Table Text Block]	Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Utility plant in service: Generation 20-70 years $ 11,282 $ 10,404 Transmission 52-75 years 1,726 1,305 Electric distribution 20-75 years 3,197 3,059 Gas distribution 28-70 years 1,565 1,507 Utility plant in service 17,770 16,275 Accumulated depreciation and amortization (5,448 ) (5,229 ) Utility plant in service, net 12,322 11,046 Nonregulated property, net: Nonregulated property gross 20-50 years 7 15 Accumulated depreciation and amortization (1 ) (5 ) Nonregulated property, net 6 10 12,328 11,056 Construction work-in-progress 493 667 Property, plant and equipment, net $ 12,821 $ 11,723
Nevada Power Company [Member]
Accounting Policies [Abstract]
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In November 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-18, which amends FASB Accounting Standards Codification ("ASC") Subtopic 230-10, “Statement of Cash Flows - Overall.” The amendments in this guidance require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In August 2016, the FASB issued ASU No. 2016-15, which amends FASB ASC Topic 230, "Statement of Cash Flows." The amendments in this guidance address the classification of eight specific cash flow issues within the statement of cash flows with the objective of reducing the existing diversity in practice. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted, and is required to be adopted retrospectively. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements. In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. During 2016, the FASB issued several ASUs that clarify the implementation guidance for ASU No. 2014-09 but do not change the core principle of the guidance. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements. Nevada Power currently does not expect the timing and amount of revenue currently recognized to be materially different after adoption of the new guidance as a majority of revenue is recognized equal to what Nevada Power has the right to invoice as it corresponds directly with the value to the customer of Nevada Power’s performance to date. Nevada Power's current plan is to quantitatively disaggregate revenue in the required financial statement footnote by customer class.
Allowance for Doubtful Accounts [Line Items]
Public Utility Property, Plant, and Equipment (NPC, SPPC, PacifiCorp) [Table Text Block]	Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Utility plant: Generation 30 - 55 years $ 4,271 $ 4,212 Distribution 20 - 65 years 3,231 3,118 Transmission 45 - 65 years 1,846 1,788 General and intangible plant 5 - 65 years 738 694 Utility plant 10,086 9,812 Accumulated depreciation and amortization (3,205 ) (2,971 ) Utility plant, net 6,881 6,841 Other non-regulated, net of accumulated depreciation and amortization 45 years 2 2 Plant, net 6,883 6,843 Construction work-in-progress 114 153 Property, plant and equipment, net $ 6,997 $ 6,996
Schedule of Accounts, Notes, Loans and Financing Receivable [Table Text Block]	The change in the balance of the allowance for doubtful accounts, which is included in accounts receivable, net on the Consolidated Balance Sheets, is summarized as follows for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 13 $ 14 $ 8 Charged to operating costs and expenses, net 16 16 14 Write-offs, net (17 ) (17 ) (8 ) Ending balance $ 12 $ 13 $ 14
Sierra Pacific Power Company [Member]
Allowance for Doubtful Accounts [Line Items]
Public Utility Property, Plant, and Equipment (NPC, SPPC, PacifiCorp) [Table Text Block]	Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Utility plant: Electric generation 30 - 60 years $ 1,137 $ 1,134 Electric distribution 20 - 70 years 1,417 1,382 Electric transmission 50 - 70 years 771 739 Electric general and intangible plant 5 - 65 years 164 139 Natural gas distribution 40 - 70 years 381 374 Natural gas general and intangible plant 5 - 60 years 15 13 Common general 5 - 65 years 267 265 Utility plant 4,152 4,046 Accumulated depreciation and amortization (1,442 ) (1,368 ) Utility plant, net 2,710 2,678 Other non-regulated, net of accumulated depreciation and amortization 60 years 5 — Plant, net 2,715 2,678 Construction work-in-progress 107 88 Property, plant and equipment, net $ 2,822 $ 2,766
Schedule of Accounts, Notes, Loans and Financing Receivable [Table Text Block]	The change in the balance of the allowance for doubtful accounts, which is included in accounts receivable, net on the Consolidated Balance Sheets, is summarized as follows for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 1 $ 2 $ 1 Charged to operating costs and expenses, net 2 1 2 Write-offs, net (1 ) (2 ) (1 ) Ending balance $ 2 $ 1 $ 2

Business Acquisitions (Tables)

Business Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2016
AltaLink [Member]
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Schedule of Business Acquisitions, by Acquisition [Table Text Block]
Business Acquisition, Pro Forma Information [Table Text Block]	The following unaudited pro forma financial information reflects the consolidated results of operations of BHE, non-recurring transaction costs incurred by both BHE and AltaLink during 2014 and the amortization of the purchase price adjustments each assuming the acquisition had taken place on January 1, 2013 (in millions): 2014 Operating revenue 17,888 Net income attributable to BHE shareholders 2,155
NV Energy, Inc. [Member]
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Business Acquisition, Pro Forma Information [Table Text Block]

Property, Plant and Equipment45

Property, Plant and Equipment, Net (Tables)	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment [Table Text Block]	Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Regulated assets: Utility generation, transmission and distribution systems 5-80 years $ 71,536 $ 69,248 Interstate natural gas pipeline assets 3-80 years 6,942 6,755 78,478 76,003 Accumulated depreciation and amortization (23,603 ) (22,682 ) Regulated assets, net 54,875 53,321 Nonregulated assets: Independent power plants 5-30 years 5,594 4,751 Other assets 3-30 years 1,002 875 6,596 5,626 Accumulated depreciation and amortization (1,060 ) (805 ) Nonregulated assets, net 5,536 4,821 Net operating assets 60,411 58,142 Construction work-in-progress 2,098 2,627 Property, plant and equipment, net $ 62,509 $ 60,769
MidAmerican Energy Company [Member]
Property, Plant and Equipment [Line Items]
Public Utility Property, Plant, and Equipment (NPC, SPPC, PacifiCorp) [Table Text Block]	Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Utility plant in service: Generation 20-70 years $ 11,282 $ 10,404 Transmission 52-75 years 1,726 1,305 Electric distribution 20-75 years 3,197 3,059 Gas distribution 28-70 years 1,565 1,507 Utility plant in service 17,770 16,275 Accumulated depreciation and amortization (5,448 ) (5,229 ) Utility plant in service, net 12,322 11,046 Nonregulated property, net: Nonregulated property gross 20-50 years 7 15 Accumulated depreciation and amortization (1 ) (5 ) Nonregulated property, net 6 10 12,328 11,056 Construction work-in-progress 493 667 Property, plant and equipment, net $ 12,821 $ 11,723
Depreciation and Amortization Rates [Table Text Block]	The average depreciation and amortization rates applied to depreciable utility plant for the years ended December 31 were as follows: 2016 2015 2014 Electric 2.8 % 3.0 % 2.8 % Gas 2.9 % 2.9 % 2.8 %
PacifiCorp [Member]
Property, Plant and Equipment [Line Items]
Public Utility Property, Plant, and Equipment (NPC, SPPC, PacifiCorp) [Table Text Block]	Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Property, plant and equipment: Generation 14 - 67 years $ 12,371 $ 12,164 Transmission 58 - 75 years 6,055 5,914 Distribution 20 - 70 years 6,590 6,408 Intangible plant (1) 5 - 62 years 884 875 Other 5 - 60 years 1,398 1,396 Property, plant and equipment in-service 27,298 26,757 Accumulated depreciation and amortization (8,793 ) (8,360 ) Net property, plant and equipment in-service 18,505 18,397 Construction work-in-progress 657 629 Total property, plant and equipment, net $ 19,162 $ 19,026 (1) Computer software costs included in intangible plant are initially assigned a depreciable life of 5 to 10 years.
Nevada Power Company [Member]
Property, Plant and Equipment [Line Items]
Public Utility Property, Plant, and Equipment (NPC, SPPC, PacifiCorp) [Table Text Block]	Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Utility plant: Generation 30 - 55 years $ 4,271 $ 4,212 Distribution 20 - 65 years 3,231 3,118 Transmission 45 - 65 years 1,846 1,788 General and intangible plant 5 - 65 years 738 694 Utility plant 10,086 9,812 Accumulated depreciation and amortization (3,205 ) (2,971 ) Utility plant, net 6,881 6,841 Other non-regulated, net of accumulated depreciation and amortization 45 years 2 2 Plant, net 6,883 6,843 Construction work-in-progress 114 153 Property, plant and equipment, net $ 6,997 $ 6,996
Sierra Pacific Power Company [Member]
Property, Plant and Equipment [Line Items]
Public Utility Property, Plant, and Equipment (NPC, SPPC, PacifiCorp) [Table Text Block]	Property, plant and equipment, net consists of the following as of December 31 (in millions): Depreciable Life 2016 2015 Utility plant: Electric generation 30 - 60 years $ 1,137 $ 1,134 Electric distribution 20 - 70 years 1,417 1,382 Electric transmission 50 - 70 years 771 739 Electric general and intangible plant 5 - 65 years 164 139 Natural gas distribution 40 - 70 years 381 374 Natural gas general and intangible plant 5 - 60 years 15 13 Common general 5 - 65 years 267 265 Utility plant 4,152 4,046 Accumulated depreciation and amortization (1,442 ) (1,368 ) Utility plant, net 2,710 2,678 Other non-regulated, net of accumulated depreciation and amortization 60 years 5 — Plant, net 2,715 2,678 Construction work-in-progress 107 88 Property, plant and equipment, net $ 2,822 $ 2,766

Jointly Owned Utility Facilit46

Jointly Owned Utility Facilities (Tables)	12 Months Ended
	Dec. 31, 2016
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Table Text Block]	The amounts shown in the table below represent the Company's share in each jointly owned facility as of December 31, 2016 (dollars in millions): Accumulated Construction Company Facility In Depreciation and Work-in- Share Service Amortization Progress PacifiCorp: Jim Bridger Nos. 1-4 67 % $ 1,420 $ 583 $ 10 Hunter No. 1 94 473 161 1 Hunter No. 2 60 296 98 — Wyodak 80 467 203 1 Colstrip Nos. 3 and 4 10 244 130 5 Hermiston 50 178 76 2 Craig Nos. 1 and 2 19 325 223 32 Hayden No. 1 25 74 32 — Hayden No. 2 13 43 20 — Foote Creek 79 39 25 — Transmission and distribution facilities Various 777 228 61 Total PacifiCorp 4,336 1,779 112 MidAmerican Energy: Louisa No. 1 88 % 766 418 9 Quad Cities Nos. 1 and 2 (1) 25 689 367 7 Walter Scott, Jr. No. 3 79 614 303 1 Walter Scott, Jr. No. 4 (2) 60 448 101 2 George Neal No. 4 41 307 154 1 Ottumwa No. 1 52 548 191 13 George Neal No. 3 72 426 174 1 Transmission facilities Various 247 86 1 Total MidAmerican Energy 4,045 1,794 35 NV Energy: Navajo 11 % 213 145 2 Silverhawk 75 248 66 3 Valmy 50 389 216 1 Transmission facilities Various 213 41 — Total NV Energy 1,063 468 6 BHE Pipeline Group - common facilities Various 286 164 — Total $ 9,730 $ 4,205 $ 153 (1) Includes amounts related to nuclear fuel. (2) Facility in-service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling $319 million and $75 million , respectively.
PacifiCorp [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Table Text Block]	The amounts shown in the table below represent PacifiCorp's share in each jointly owned facility as of December 31, 2016 (dollars in millions): Facility Accumulated Construction PacifiCorp in Depreciation and Work-in- Share Service Amortization Progress Jim Bridger Nos. 1 - 4 67 % $ 1,420 $ 583 $ 10 Hunter No. 1 94 473 161 1 Hunter No. 2 60 296 98 — Wyodak 80 467 203 1 Colstrip Nos. 3 and 4 10 244 130 5 Hermiston 50 178 76 2 Craig Nos. 1 and 2 19 325 223 32 Hayden No. 1 25 74 32 — Hayden No. 2 13 43 20 — Foote Creek 79 39 25 — Transmission and distribution facilities Various 777 228 61 Total $ 4,336 $ 1,779 $ 112
MidAmerican Energy Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Table Text Block]	The amounts shown in the table below represent MidAmerican Energy's share in each jointly owned facility as of December 31, 2016 (dollars in millions): Accumulated Construction Company Plant in Depreciation and Work-in- Share Service Amortization Progress Louisa Unit No. 1 88.0 % $ 766 $ 418 $ 9 Quad Cities Unit Nos. 1 & 2 (1) 25.0 689 367 7 Walter Scott, Jr. Unit No. 3 79.1 614 303 1 Walter Scott, Jr. Unit No. 4 (2) 59.7 448 101 2 George Neal Unit No. 4 40.6 307 154 1 Ottumwa Unit No. 1 52.0 548 191 13 George Neal Unit No. 3 72.0 426 174 1 Transmission facilities (3) Various 247 86 1 Total $ 4,045 $ 1,794 $ 35 (1) Includes amounts related to nuclear fuel. (2) Plant in service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling $319 million and $75 million , respectively. (3) Includes 345 and 161 kilovolt transmission lines and substations.
Nevada Power Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Table Text Block]	The amounts shown in the table below represent Nevada Power 's share in each jointly owned facility as of December 31 , 2016 (dollars in millions): Nevada Construction Power's Utility Accumulated Work-in- Share Plant Depreciation Progress Silverhawk Generating Station 75 % $ 248 $ 66 $ 3 Navajo Generating Station 11 213 145 2 ON Line Transmission Line 24 145 12 — Other Transmission Facilities Various 56 26 — Total $ 662 $ 249 $ 5
Sierra Pacific Power Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Facilities [Table Text Block]	The amounts shown in the table below represent Sierra Pacific 's share in each jointly owned facility as of December 31 , 2016 (dollars in millions): Sierra Construction Pacific's Utility Accumulated Work-in- Share Plant Depreciation Progress Valmy Generating Station 50 % $ 389 $ 216 $ 1 ON Line Transmission Line 1 8 1 — Valmy Transmission 50 4 2 — Total $ 401 $ 219 $ 1

Regulatory Matters (Tables)

Regulatory Matters (Tables)	12 Months Ended
	Dec. 31, 2016
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets [Table Text Block]	Regulatory assets represent costs that are expected to be recovered in future regulated rates. The Company's regulatory assets reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Deferred income taxes (1) 27 years $ 1,754 $ 1,577 Employee benefit plans (2) 17 years 816 778 Asset disposition costs Various 281 307 Deferred net power costs 1 year 38 140 Asset retirement obligations 12 years 301 281 Unrealized loss on regulated derivative contracts 5 years 154 250 Abandoned projects 3 years 159 136 Unamortized contract values 7 years 98 110 Other Various 856 706 Total regulatory assets $ 4,457 $ 4,285 Reflected as: Current assets $ 150 $ 130 Noncurrent assets 4,307 4,155 Total regulatory assets $ 4,457 $ 4,285 (1) Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse. (2) Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.
Regulatory Liabilities [Table Text Block]	Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. The Company's regulatory liabilities reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Cost of removal (1) 27 years $ 2,242 $ 2,167 Deferred net power costs 1 years 64 206 Asset retirement obligations 35 years 122 147 Levelized depreciation 23 years 244 199 Impact fees 6 years 90 — Employee benefit plans (2) 12 years 25 13 Unrealized gain on regulated derivative contracts 1 year 6 — Other Various 327 301 Total regulatory liabilities $ 3,120 $ 3,033 Reflected as: Current liabilities $ 187 $ 402 Noncurrent liabilities 2,933 2,631 Total regulatory liabilities $ 3,120 $ 3,033 (1) Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost. (2) Represents amounts not yet recognized as a component of net periodic benefit cost that are to be returned to customers in future periods when recognized.
PacifiCorp [Member]
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets [Table Text Block]	Regulatory assets represent costs that are expected to be recovered in future rates. PacifiCorp's regulatory assets reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Deferred income taxes (1) 26 years $ 421 $ 437 Employee benefit plans (2) 21 years 525 499 Utah mine disposition (3) Various 166 186 Unamortized contract values 7 years 98 110 Deferred net power costs 1 year 33 86 Unrealized loss on derivative contracts 5 years 73 133 Asset retirement obligation 20 years 82 65 Other Various 145 169 Total regulatory assets $ 1,543 $ 1,685 Reflected as: Current assets $ 53 $ 102 Noncurrent assets 1,490 1,583 Total regulatory assets $ 1,543 $ 1,685 (1) Amounts primarily represent income tax benefits and expense related to certain property-related basis differences and other various items that PacifiCorp is required to pass on to its customers. (2) Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in rates when recognized. (3) Amounts represent regulatory assets established as a result of the Utah mine disposition discussed below for the net property, plant and equipment not considered probable of disallowance and for the portion of losses associated with the assets held for sale, UMWA 1974 Pension Plan withdrawal and closure costs incurred to date considered probable of recovery.
Regulatory Liabilities [Table Text Block]	Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. PacifiCorp's regulatory liabilities reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Cost of removal (1) 26 years $ 917 $ 894 Deferred income taxes Various 9 12 Other Various 106 66 Total regulatory liabilities $ 1,032 $ 972 Reflected as: Current liabilities $ 54 $ 34 Noncurrent liabilities 978 938 Total regulatory liabilities $ 1,032 $ 972 (1) Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
MidAmerican Energy Company [Member]
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets [Table Text Block]	Regulatory assets represent costs that are expected to be recovered in future regulated rates. MidAmerican Energy's regulatory assets reflected on the Balance Sheets consist of the following as of December 31 (in millions): Average Remaining Life 2016 2015 Deferred income taxes, net (1) 29 years $ 985 $ 858 Asset retirement obligations (2) 9 years 105 94 Employee benefit plans (3) 11 years 40 39 Unrealized loss on regulated derivative contracts 1 year 2 20 Other Various 29 33 Total $ 1,161 $ 1,044 (1) Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse. (2) Amount predominantly relates to asset retirement obligations for fossil-fueled and wind-powered generating facilities. Refer to Note 12 for a discussion of asset retirement obligations. (3) Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.
Regulatory Liabilities [Table Text Block]	Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. MidAmerican Energy's regulatory liabilities reflected on the Balance Sheets consist of the following as of December 31 (in millions): Average Remaining Life 2016 2015 Cost of removal accrual (1) 29 years $ 665 $ 653 Asset retirement obligations (2) 36 years 117 140 Pre-funded AFUDC on transmission MVPs (3) 56 years 35 19 Iowa electric revenue sharing accrual (4) 1 year 30 — Employee benefit plans (5) 11 years 12 — Unrealized gain on regulated derivative contracts 1 year 6 — Other Various 18 19 Total $ 883 $ 831 (1) Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing utility plant in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost. (2) Amount predominantly represents the excess of nuclear decommission trust assets over the related asset retirement obligation. Refer to Note 12 for a discussion of asset retirement obligations. (3) Represents AFUDC accrued on transmission MVPs that is deducted from rate base as a result of the inclusion of related construction work-in-progress in rate base. (4) Represents current-year accruals under a regulatory arrangement in Iowa in which equity returns exceeding specified thresholds reduce utility plant upon final determination. (5) Represents amounts not yet recognized as a component of net periodic benefit cost that are to be returned to customers in future periods when recognized.
Nevada Power Company [Member]
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets [Table Text Block]	Regulatory assets represent costs that are expected to be recovered in future rates. Nevada Power 's regulatory assets reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Deferred income taxes (1) 27 years $ 141 $ 149 Merger costs from 1999 merger 28 years 136 143 Deferred operating costs 20 years 127 87 Decommissioning costs 7 years 114 121 Employee benefit plans (2) 10 years 105 98 Abandoned projects 3 years 75 91 Asset retirement obligations 7 years 74 79 Legacy meters 16 years 60 64 Merrill Lynch deferred energy costs 3 years 40 56 Other Various 148 169 Total regulatory assets $ 1,020 $ 1,057 Reflected as: Current assets $ 20 $ — Other assets 1,000 1,057 Total regulatory assets $ 1,020 $ 1,057 (1) Amounts represent income tax benefits related to accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse. (2) Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.
Regulatory Liabilities [Table Text Block]	Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. Nevada Power 's regulatory liabilities reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Cost of removal (1) 33 years $ 294 $ 273 Impact fees 6 years 90 — Energy efficiency program 1 year 37 34 Deferred energy costs 1 year — 139 Other Various 32 31 Total regulatory liabilities $ 453 $ 477 Reflected as: Current liabilities $ 37 $ 173 Other long-term liabilities 416 304 Total regulatory liabilities $ 453 $ 477 (1) Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
Sierra Pacific Power Company [Member]
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets [Table Text Block]	Regulatory assets represent costs that are expected to be recovered in future rates. Sierra Pacific 's regulatory assets reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Employee benefit plans (1) 10 years $ 128 $ 126 Deferred income taxes (2) 27 years 85 90 Merger costs from 1999 merger 30 years 80 83 Abandoned projects 9 years 39 44 Renewable energy programs 1 year 25 — Losses on reacquired debt 17 years 22 22 Other Various 56 67 Total regulatory assets $ 435 $ 432 Reflected as: Current assets $ 25 $ — Other assets 410 432 Total regulatory assets $ 435 $ 432 (1) Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized. (2) Amounts represent income tax benefits related to accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
Regulatory Liabilities [Table Text Block]	Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. Sierra Pacific 's regulatory liabilities reflected on the Consolidated Balance Sheets consist of the following as of December 31 (in millions): Weighted Average Remaining Life 2016 2015 Cost of removal (1) 39 years $ 205 $ 208 Deferred energy costs 1 year 64 66 Renewable energy program 1 year — 8 Other Various 21 26 Total regulatory liabilities $ 290 $ 308 Reflected as: Current liabilities $ 69 $ 78 Other long-term liabilities 221 230 Total regulatory liabilities $ 290 $ 308 (1) Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.

Investments and Restricted Ca48

Investments and Restricted Cash and Investments (Tables)	12 Months Ended
	Dec. 31, 2016
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Investments and Restricted Cash and Investments [Table Text Block]	Investments and restricted cash and investments consists of the following as of December 31 (in millions): 2016 2015 Investments: BYD Company Limited common stock $ 1,185 $ 1,238 Rabbi trusts 403 380 Other 106 130 Total investments 1,694 1,748 Equity method investments: Electric Transmission Texas, LLC 672 585 Bridger Coal Company 165 190 BHE Renewables tax equity investments 741 168 Other 142 160 Total equity method investments 1,720 1,103 Restricted cash and investments: Quad Cities Station nuclear decommissioning trust funds 460 429 Solar Star and Topaz Projects 64 95 Other 218 129 Total restricted cash and investments 742 653 Total investments and restricted cash and investments $ 4,156 $ 3,504 Reflected as: Current assets $ 211 $ 137 Noncurrent assets 3,945 3,367 Total investments and restricted cash and investments $ 4,156 $ 3,504
MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Investments and Restricted Cash and Investments [Table Text Block]	Investments and restricted cash and investments consists of the following amounts as of December 31 (in millions): 2016 2015 Nuclear decommissioning trust $ 460 $ 429 Rabbi trusts 184 175 Auction rate securities — 26 Other 9 4 Total $ 653 $ 634

Short-Term Debt and Credit Fa49

Short-Term Debt and Credit Facilities (Tables)	12 Months Ended
	Dec. 31, 2016
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Short-Term Debt and Credit Facilities The following table summarizes BHE's and its subsidiaries' availability under their credit facilities as of December 31, (in millions): MidAmerican NV Northern BHE PacifiCorp Funding Energy Powergrid AltaLink Other Total (1) 2016: Credit facilities $ 2,000 $ 1,000 $ 609 $ 650 $ 185 $ 986 $ 915 $ 6,345 Less: Short-term debt (834 ) (270 ) (99 ) — — (289 ) (377 ) (1,869 ) Tax-exempt bond support and letters of credit (7 ) (142 ) (220 ) (80 ) — (8 ) — (457 ) Net credit facilities $ 1,159 $ 588 $ 290 $ 570 $ 185 $ 689 $ 538 $ 4,019 2015: Credit facilities $ 2,000 $ 1,200 $ 609 $ 650 $ 221 $ 813 $ 928 $ 6,421 Less: Short-term debt (253 ) (20 ) — — — (401 ) (300 ) (974 ) Tax-exempt bond support and letters of credit (51 ) (160 ) (195 ) — — (9 ) — (415 ) Net credit facilities $ 1,696 $ 1,020 $ 414 $ 650 $ 221 $ 403 $ 628 $ 5,032 (1) The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method. As of December 31, 2016 , the Company was in compliance with the covenants of its credit facilities and letter of credit arrangements. BHE BHE has a $2.0 billion unsecured credit facility expiring in June 2019 with two one-year extension options subject to bank consent. The credit facility, which is for general corporate purposes and also supports BHE's commercial paper program and provides for the issuance of letters of credit, has a variable interest rate based on the LIBOR or a base rate, at BHE's option, plus a spread that varies based on BHE's senior unsecured long-term debt credit ratings. As of December 31, 2016 and 2015 , the weighted average interest rate on commercial paper borrowings outstanding was 0.88% and 0.66% , respectively. The credit facility requires that BHE's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.70 to 1.0 as of the last day of each quarter. As of December 31, 2016 and 2015 , BHE had $123 million and $142 million , respectively, of letters of credit outstanding, of which $7 million and $51 million as of December 31, 2016 and 2015 were issued under the credit facilities. These letters of credit primarily support power purchase agreements and debt service requirements at certain subsidiaries of BHE Renewables, LLC and expire through December 2018. PacifiCorp PacifiCorp has a $600 million unsecured credit facility expiring in March 2018 and a $400 million unsecured credit facility expiring in June 2019 each with two one-year extension options subject to bank consent. These credit facilities, which support PacifiCorp's commercial paper program, certain series of its tax-exempt bond obligations and provide for the issuance of letters of credit, have a variable interest rate based on LIBOR or a base rate, at PacifiCorp's option, plus a spread that varies based on PacifiCorp's credit ratings for its senior unsecured long-term debt securities. As of December 31, 2016 and 2015 , the weighted average interest rate on commercial paper borrowings outstanding was 0.96% and 0.65% , respectively. These credit facilities require that PacifiCorp's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.65 to 1.0 as of the last day of each quarter. As of December 31, 2016 and 2015 , PacifiCorp had $255 million and $310 million , respectively, of fully available letters of credit issued under committed arrangements, of which $10 million as of December 31, 2015 were issued under the credit facilities. These letters of credit support PacifiCorp's variable-rate tax-exempt bond obligations and expire through March 2019. MidAmerican Funding MidAmerican Energy has a $600 million unsecured credit facility expiring in March 2018 with two one-year extension options subject to bank consent. The credit facility, which supports MidAmerican Energy's commercial paper program and its variable-rate tax-exempt bond obligations and provides for the issuance of letters of credit, has a variable interest rate based on LIBOR or a base rate, at MidAmerican Energy's option, plus a spread that varies based on MidAmerican Energy's credit ratings for senior unsecured long-term debt securities. As of December 31, 2016 , the weighted average interest rate on commercial paper borrowings outstanding was 0.73% . The credit facility requires that MidAmerican Energy's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.65 to 1.0 as of the last day of each quarter. NV Energy Nevada Power has a $400 million secured credit facility expiring in March 2018 and Sierra Pacific has a $250 million secured credit facility expiring in March 2018 each with two one-year extension options subject to bank consent. These credit facilities, which are for general corporate purposes and provide for the issuance of letters of credit, have a variable interest rate based on LIBOR or a base rate, at each of the Nevada Utilities' option, plus a spread that varies based on each of the Nevada Utilities' credit ratings for its senior secured long-term debt securities. Amounts due under each credit facility are collateralized by each of the Nevada Utilities' general and refunding mortgage bonds. The credit facilities require that each of the Nevada Utilities' ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.68 to 1.0 as of the last day of each quarter. Northern Powergrid Northern Powergrid has a £150 million unsecured credit facility expiring in April 2020. The credit facility has a variable interest rate based on sterling LIBOR plus a spread that varies based on its credit ratings. The credit facility requires that the ratio of consolidated senior total net debt, including current maturities, to regulated asset value not exceed 0.8 to 1.0 at Northern Powergrid and 0.65 to 1.0 at Northern Powergrid (Northeast) Limited and Northern Powergrid (Yorkshire) plc as of June 30 and December 31. Northern Powergrid 's interest coverage ratio shall not be less than 2.5 to 1.0. AltaLink ALP has a C$750 million secured revolving credit facility expiring in December 2018 with a one-year extension option subject to bank consent. The credit facility, which provides support for borrowings under the unsecured commercial paper program and may also be used for general corporate purposes, has a variable interest rate based on the Canadian bank prime lending rate or a spread above the Bankers' Acceptance rate, at ALP 's option, based on ALP 's credit ratings for its senior secured long-term debt securities. In addition, ALP has a C$75 million secured revolving credit facility expiring in December 2018 with a one-year extension option subject to bank consent. The credit facility, which may be used for general corporate purposes, capital expenditures and letters of credit, has a variable interest rate based on the Canadian bank prime lending rate, United States base rate, United States LIBOR loan rate, or a spread above the Bankers' Acceptance rate, at ALP 's option, based on ALP 's credit ratings for its senior secured long-term debt securities. At the renewal date, ALP has the option to convert these facilities to one-year term facilities. The credit facilities require the consolidated indebtedness to total capitalization not exceed 0.75 to 1.0 measured as of the last day of each quarter. As of December 31, 2016 and 2015 , ALP had $26 million and $324 million outstanding under these facilities at a weighted average interest rate of 0.99% and 0.94% , respectively. AltaLink Investments, L.P. has a C$300 million unsecured revolving term credit facility expiring in December 2021 and a C$200 million unsecured revolving credit facility expiring in December 2017 each with a one-year extension option subject to bank consent. The credit facilities, which may be used for operating expenses, capital expenditures, working capital needs and letters of credit to a maximum of C$10 million , have a variable interest rate based on the Canadian bank prime lending rate, United States base rate, United States LIBOR loan rate, or a spread above the Bankers' Acceptance rate, at AltaLink Investments, L.P.'s option, based on AltaLink Investments, L.P.'s credit ratings for its senior unsecured long-term debt securities. The credit facilities require the consolidated total debt to capitalization to not exceed 0.8 to 1.0 and earnings before interest, taxes, depreciation and amortization to interest expense for the four fiscal quarters ended to not be less than 2.25 to 1.0 measured as of the last day of each quarter. As of December 31, 2016 and 2015 , AltaLink Investments, L.P. had $263 million and $77 million outstanding under these facilities at a weighted average interest rate of 1.74% and 2.09% , respectively. HomeServices HomeServices has a $350 million unsecured credit facility expiring in July 2018. The credit facility has a variable interest rate based on the prime lending rate or the LIBOR, at HomeServices' option, plus a spread that varies based on HomeServices' Total Leverage Ratio as defined in the agreement. As of December 31, 2016 , HomeServices had $50 million outstanding under its credit facility with a weighted average interest rate of 1.77% . Through its subsidiaries, HomeServices maintains mortgage lines of credit totaling $565 million and $578 million as of December 31, 2016 and 2015 , respectively, used for mortgage banking activities that expire beginning in February 2017 through December 2017 or are due on demand. The mortgage lines of credit have variable rates based on LIBOR plus a spread. Collateral for these credit facilities is comprised of residential property being financed and is equal to the loans funded with the facilities. As of December 31, 2016 and 2015 , HomeServices had $327 million and $300 million , respectively, outstanding under these mortgage lines of credit at a weighted average interest rate of 2.77% and 2.42% , respectively. BHE Renewables Letters of Credit In connection with their bond offerings, Topaz and Solar Star entered into separate letter of credit and reimbursement facilities totaling $627 million . Letters of credit issued under the letter of credit facilities will be used to (a) provide security under the power purchase agreement and large generator interconnection agreements, (b) fund the debt service reserve requirement and the operation and maintenance debt service reserve requirement and (c) provide security for remediation and mitigation liabilities. As of December 31, 2016 and 2015 , $599 million and $600 million , respectively, of letters of credit had been issued under these facilities. As of December 31, 2016 and 2015 , certain renewable projects collectively have letters of credit outstanding of $106 million and $65 million , respectively, primarily in support of the power purchase agreements associated with the projects.
Short-Term Debt and Credit Facilities [Table Text Block]	The following table summarizes BHE's and its subsidiaries' availability under their credit facilities as of December 31, (in millions): MidAmerican NV Northern BHE PacifiCorp Funding Energy Powergrid AltaLink Other Total (1) 2016: Credit facilities $ 2,000 $ 1,000 $ 609 $ 650 $ 185 $ 986 $ 915 $ 6,345 Less: Short-term debt (834 ) (270 ) (99 ) — — (289 ) (377 ) (1,869 ) Tax-exempt bond support and letters of credit (7 ) (142 ) (220 ) (80 ) — (8 ) — (457 ) Net credit facilities $ 1,159 $ 588 $ 290 $ 570 $ 185 $ 689 $ 538 $ 4,019 2015: Credit facilities $ 2,000 $ 1,200 $ 609 $ 650 $ 221 $ 813 $ 928 $ 6,421 Less: Short-term debt (253 ) (20 ) — — — (401 ) (300 ) (974 ) Tax-exempt bond support and letters of credit (51 ) (160 ) (195 ) — — (9 ) — (415 ) Net credit facilities $ 1,696 $ 1,020 $ 414 $ 650 $ 221 $ 403 $ 628 $ 5,032 (1) The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.
Sierra Pacific Power Company [Member]
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Credit Facility The following table summarizes Sierra Pacific's availability under its credit facilities as of December 31 (in millions): 2016 2015 Credit facilities $ 250 $ 250 Less - Water Facilities Refunding Revenue Bond support (80 ) — Net credit facilities $ 170 $ 250 Sierra Pacific has a $250 million secured credit facility expiring in March 2018. The credit facility, which is for general corporate purposes for the issuance of letters of credit, has a variable interest rate based on London Interbank Offered Rate or a base rate, at Sierra Pacific 's option, plus a spread that varies based on Sierra Pacific 's credit ratings for its senior secured long‑term debt securities. Amounts due under Sierra Pacific 's credit facility are collateralized by Sierra Pacific 's general and refunding mortgage bonds. The credit facility requires Sierra Pacific 's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.68 to 1.0 as of the last day of each quarter.
Short-Term Debt and Credit Facilities [Table Text Block]	The following table summarizes Sierra Pacific's availability under its credit facilities as of December 31 (in millions): 2016 2015 Credit facilities $ 250 $ 250 Less - Water Facilities Refunding Revenue Bond support (80 ) — Net credit facilities $ 170 $ 250
PacifiCorp [Member]
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Short-term Debt and Other Financing Agreements The following table summarizes PacifiCorp's availability under its credit facilities as of December 31 (in millions): 2016: Credit facilities $ 1,000 Less: Short-term debt (270 ) Tax-exempt bond support (142 ) Net credit facilities $ 588 2015: Credit facilities $ 1,200 Less: Short-term debt (20 ) Tax-exempt bond support and letters of credit (160 ) Net credit facilities $ 1,020 PacifiCorp has a $600 million unsecured credit facility expiring in March 2018 and a $400 million unsecured credit facility with a stated maturity of June 2019 and which has two one-year extension options subject to bank consent. These credit facilities, which support PacifiCorp's commercial paper program, certain series of its tax-exempt bond obligations and provide for the issuance of letters of credit, have a variable interest rate based on the London Interbank Offered Rate or a base rate, at PacifiCorp's option, plus a spread that varies based on PacifiCorp's credit ratings for its senior unsecured long-term debt securities. As of December 31, 2016 and 2015 , the weighted average interest rate on commercial paper borrowings outstanding was 0.96% and 0.65% , respectively. These credit facilities require that PacifiCorp's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.65 to 1.0 as of the last day of each quarter. As of December 31, 2016 , PacifiCorp was in compliance with the covenants of its credit facilities. As of December 31, 2016 and 2015 , PacifiCorp had $255 million and $310 million , respectively, of fully available letters of credit issued under committed arrangements, of which $10 million as of December 31, 2015 were issued under the credit facilities. These letters of credit support PacifiCorp's variable-rate tax-exempt bond obligations and expire through March 2019. As of December 31, 2016 , PacifiCorp had approximately $14 million of additional letters of credit issued on its behalf to provide credit support for certain transactions as required by third parties. These letters of credit were all undrawn as of December 31, 2016 and have provisions that automatically extend the annual expiration dates for an additional year unless the issuing bank elects not to renew a letter of credit prior to the expiration date.
Short-Term Debt and Credit Facilities [Table Text Block]	The following table summarizes PacifiCorp's availability under its credit facilities as of December 31 (in millions): 2016: Credit facilities $ 1,000 Less: Short-term debt (270 ) Tax-exempt bond support (142 ) Net credit facilities $ 588 2015: Credit facilities $ 1,200 Less: Short-term debt (20 ) Tax-exempt bond support and letters of credit (160 ) Net credit facilities $ 1,020
MidAmerican Energy Company [Member]
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Short-Term Debt and Credit Facilities Interim financing of working capital needs and the construction program is obtained from unaffiliated parties through the sale of commercial paper or short-term borrowing from banks. MidAmerican Energy has a $600 million unsecured credit facility expiring in March 2018 . The credit facility, which supports MidAmerican Energy's commercial paper program and its variable-rate tax-exempt bond obligations and provides for the issuance of letters of credit, has a variable interest rate based on the London Interbank Offered Rate ("LIBOR") or a base rate, at MidAmerican Energy's option, plus a spread that varies based on MidAmerican Energy's credit ratings for senior unsecured long-term debt securities. In addition, MidAmerican Energy has a $5 million unsecured credit facility, which expires in June 2017 and has a variable interest rate based on LIBOR plus a spread. As of December 31, 2016 , the weighted average interest rate on commercial paper borrowings outstanding was 0.73% . The $600 million credit facility requires that MidAmerican Energy's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.65 to 1.0 as of the last day of any quarter. As of December 31, 2016 , MidAmerican Energy was in compliance with the covenants of its credit facilities. MidAmerican Energy has authority from the FERC to issue commercial paper and bank notes aggregating $605 million through February 28, 2017 , and $905 million from March 1, 2017 , through February 28, 2019 . The following table summarizes MidAmerican Energy's availability under its two unsecured revolving credit facilities as of December 31 (in millions): 2016 2015 Credit facilities $ 605 $ 605 Less: Short-term debt outstanding (99 ) — Variable-rate tax-exempt bond support (220 ) (195 ) Net credit facilities $ 286 $ 410
Short-Term Debt and Credit Facilities [Table Text Block]	The following table summarizes MidAmerican Energy's availability under its two unsecured revolving credit facilities as of December 31 (in millions): 2016 2015 Credit facilities $ 605 $ 605 Less: Short-term debt outstanding (99 ) — Variable-rate tax-exempt bond support (220 ) (195 ) Net credit facilities $ 286 $ 410
Nevada Power Company [Member]
Line of Credit Facility [Line Items]
Short-term Debt [Text Block]	Credit Facility Nevada Power has a $400 million secured credit facility expiring in March 2018. The credit facility, which is for general corporate purposes for the issuance of letters of credit, has a variable interest rate based on London Interbank Offered Rate or a base rate, at Nevada Power 's option, plus a spread that varies based on Nevada Power 's credit ratings for its senior secured long‑term debt securities. As of December 31 , 2016 and 2015 , Nevada Power had no borrowings outstanding under the credit facility. Amounts due under Nevada Power 's credit facility are collateralized by Nevada Power 's general and refunding mortgage bonds. The credit facility requires Nevada Power 's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.68 to 1.0 as of the last day of each quarter.

BHE Debt (Tables)

BHE Debt (Tables)	12 Months Ended
	Dec. 31, 2016
MEHC Debt [Abstract]
BHE Debt [Table Text Block]	Junior Subordinated Debentures BHE junior subordinated debentures consists of the following as of December 31 (in millions): Par Value 2016 2015 Junior subordinated debentures, due 2043 $ — $ — $ 1,444 Junior subordinated debentures, due 2044 944 944 1,500 Total BHE junior subordinated debentures - noncurrent $ 944 $ 944 $ 2,944 Senior Debt BHE senior debt represents unsecured senior obligations of BHE that are redeemable in whole or in part at any time generally with make-whole premiums. BHE senior debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (in millions): Par Value 2016 2015 1.10% Senior Notes, due 2017 $ 400 $ 400 $ 399 5.75% Senior Notes, due 2018 650 649 648 2.00% Senior Notes, due 2018 350 349 348 2.40% Senior Notes, due 2020 350 349 348 3.75% Senior Notes, due 2023 500 497 497 3.50% Senior Notes, due 2025 400 397 397 8.48% Senior Notes, due 2028 475 477 477 6.125% Senior Bonds, due 2036 1,700 1,690 1,690 5.95% Senior Bonds, due 2037 550 547 547 6.50% Senior Bonds, due 2037 1,000 987 987 5.15% Senior Notes, due 2043 750 739 739 4.50% Senior Notes, due 2045 750 737 737 Total BHE Senior Debt $ 7,875 $ 7,818 $ 7,814 Reflected as: Current liabilities $ 400 $ — Noncurrent liabilities 7,418 7,814 Total BHE Senior Debt $ 7,818 $ 7,814 Long-term debt of subsidiaries consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31 (in millions): Par Value 2016 2015 PacifiCorp $ 7,120 $ 7,079 $ 7,159 MidAmerican Funding 4,657 4,592 4,560 NV Energy 4,569 4,582 4,860 Northern Powergrid 2,351 2,379 2,772 BHE Pipeline Group 995 990 1,040 BHE Transmission 4,068 4,058 3,467 BHE Renewables 3,716 3,674 3,356 Total subsidiary debt $ 27,476 $ 27,354 $ 27,214 Reflected as: Current liabilities $ 606 $ 1,148 Noncurrent liabilities 26,748 26,066 Total subsidiary debt $ 27,354 $ 27,214 MidAmerican Energy's long-term debt consists of the following, including amounts maturing within one year and unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 First mortgage bonds: 2.40%, due 2019 $ 500 $ 499 $ 499 3.70%, due 2023 250 248 248 3.50%, due 2024 500 501 502 4.80%, due 2043 350 345 345 4.40%, due 2044 400 394 394 4.25%, due 2046 450 445 444 Notes: 5.95% Series, due 2017 250 250 250 5.3% Series, due 2018 350 350 349 6.75% Series, due 2031 400 396 395 5.75% Series, due 2035 300 298 298 5.8% Series, due 2036 350 347 347 Transmission upgrade obligation, 4.45% and 3.42% due through 2035 and 2036, respectively 10 7 4 Variable-rate tax-exempt bond obligation series: (weighted average interest rate- 2016-0.76%, 2015-0.03%): Due 2016 — — 33 Due 2017 — — 4 Due 2023, issued in 1993 7 7 7 Due 2023, issued in 2008 57 57 57 Due 2024 35 35 35 Due 2025 13 13 13 Due 2036 33 33 — Due 2038 45 45 45 Due 2046 30 29 — Capital lease obligations - 4.16%, due through 2020 2 2 2 Total $ 4,332 $ 4,301 $ 4,271

Subsidiary Debt (Tables)

Subsidiary Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	Junior Subordinated Debentures BHE junior subordinated debentures consists of the following as of December 31 (in millions): Par Value 2016 2015 Junior subordinated debentures, due 2043 $ — $ — $ 1,444 Junior subordinated debentures, due 2044 944 944 1,500 Total BHE junior subordinated debentures - noncurrent $ 944 $ 944 $ 2,944 Senior Debt BHE senior debt represents unsecured senior obligations of BHE that are redeemable in whole or in part at any time generally with make-whole premiums. BHE senior debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (in millions): Par Value 2016 2015 1.10% Senior Notes, due 2017 $ 400 $ 400 $ 399 5.75% Senior Notes, due 2018 650 649 648 2.00% Senior Notes, due 2018 350 349 348 2.40% Senior Notes, due 2020 350 349 348 3.75% Senior Notes, due 2023 500 497 497 3.50% Senior Notes, due 2025 400 397 397 8.48% Senior Notes, due 2028 475 477 477 6.125% Senior Bonds, due 2036 1,700 1,690 1,690 5.95% Senior Bonds, due 2037 550 547 547 6.50% Senior Bonds, due 2037 1,000 987 987 5.15% Senior Notes, due 2043 750 739 739 4.50% Senior Notes, due 2045 750 737 737 Total BHE Senior Debt $ 7,875 $ 7,818 $ 7,814 Reflected as: Current liabilities $ 400 $ — Noncurrent liabilities 7,418 7,814 Total BHE Senior Debt $ 7,818 $ 7,814 Long-term debt of subsidiaries consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31 (in millions): Par Value 2016 2015 PacifiCorp $ 7,120 $ 7,079 $ 7,159 MidAmerican Funding 4,657 4,592 4,560 NV Energy 4,569 4,582 4,860 Northern Powergrid 2,351 2,379 2,772 BHE Pipeline Group 995 990 1,040 BHE Transmission 4,068 4,058 3,467 BHE Renewables 3,716 3,674 3,356 Total subsidiary debt $ 27,476 $ 27,354 $ 27,214 Reflected as: Current liabilities $ 606 $ 1,148 Noncurrent liabilities 26,748 26,066 Total subsidiary debt $ 27,354 $ 27,214 MidAmerican Energy's long-term debt consists of the following, including amounts maturing within one year and unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 First mortgage bonds: 2.40%, due 2019 $ 500 $ 499 $ 499 3.70%, due 2023 250 248 248 3.50%, due 2024 500 501 502 4.80%, due 2043 350 345 345 4.40%, due 2044 400 394 394 4.25%, due 2046 450 445 444 Notes: 5.95% Series, due 2017 250 250 250 5.3% Series, due 2018 350 350 349 6.75% Series, due 2031 400 396 395 5.75% Series, due 2035 300 298 298 5.8% Series, due 2036 350 347 347 Transmission upgrade obligation, 4.45% and 3.42% due through 2035 and 2036, respectively 10 7 4 Variable-rate tax-exempt bond obligation series: (weighted average interest rate- 2016-0.76%, 2015-0.03%): Due 2016 — — 33 Due 2017 — — 4 Due 2023, issued in 1993 7 7 7 Due 2023, issued in 2008 57 57 57 Due 2024 35 35 35 Due 2025 13 13 13 Due 2036 33 33 — Due 2038 45 45 45 Due 2046 30 29 — Capital lease obligations - 4.16%, due through 2020 2 2 2 Total $ 4,332 $ 4,301 $ 4,271
Maturities of Long-term Debt [Table Text Block]	Annual Repayments of Long-Term Debt The annual repayments of BHE and subsidiary debt for the years beginning January 1, 2017 and thereafter, excluding fair value adjustments and unamortized premiums, discounts and debt issuance costs, are as follows (in millions): 2022 and 2017 2018 2019 2020 2021 Thereafter Total BHE senior notes $ 400 $ 1,000 $ — $ 350 $ — $ 6,125 $ 7,875 BHE junior subordinated debentures — — — — — 944 944 PacifiCorp 58 588 352 40 425 5,657 7,120 MidAmerican Funding 251 351 500 2 1 3,552 4,657 NV Energy 18 840 519 336 27 2,829 4,569 Northern Powergrid — 49 49 418 — 1,835 2,351 BHE Pipeline Group 66 329 — — 200 400 995 BHE Transmission — 151 151 245 3 3,518 4,068 BHE Renewables 213 236 528 161 167 2,411 3,716 Totals $ 1,006 $ 3,544 $ 2,099 $ 1,552 $ 823 $ 27,271 $ 36,295
MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Maturities of Long-term Debt [Table Text Block]	The annual repayments of MidAmerican Energy's long-term debt for the years beginning January 1, 2017 , and thereafter, excluding unamortized premiums, discounts and debt issuance costs, are as follows (in millions): 2017 $ 251 2018 351 2019 500 2020 2 2021 1 2022 and thereafter 3,227
Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	Sierra Pacific 's long-term debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 General and refunding mortgage securities: 6.000% Series M, due 2016 $ — $ — $ 450 3.375% Series T, due 2023 250 248 248 2.600% Series U, due 2026 400 395 — 6.750% Series P, due 2037 252 255 255 Tax-exempt refunding revenue bond obligations: Fixed-rate series: 1.250% Pollution Control Series 2016A, due 2029 (1) 20 20 — 1.500% Gas Facilities Series 2016A, due 2031 (1) 58 58 — 3.000% Gas and Water Series 2016B, due 2036 (2) 60 64 — Variable-rate series (2016-0.788% to 0.800%, 2015-0.733% to 1.054%): Pollution Control Series 2006A, due 2031 — — 58 Pollution Control Series 2006B, due 2036 — — 74 Pollution Control Series 2006C, due 2036 — — 80 Water Facilities Series 2016C, due 2036 30 29 — Water Facilities Series 2016D, due 2036 25 25 — Water Facilities Series 2016E, due 2036 25 25 — Capital and financial lease obligations - 2.700% to 10.130%, due through 2054 34 34 37 Total long-term debt and financial and capital leases $ 1,154 $ 1,153 $ 1,202 Reflected as: Current portion of long-term debt and financial and capital lease obligations $ 1 $ 453 Long-term debt and financial and capital lease obligations 1,152 749 Total long-term debt and financial and capital leases $ 1,153 $ 1,202 (1) Subject to mandatory purchase by Sierra Pacific in June 2019 at which date the interest rate may be adjusted from time to time. (2) Subject to mandatory purchase by Sierra Pacific in June 2022 at which date the interest rate may be adjusted from time to time.
Maturities of Long-term Debt [Table Text Block]	The annual repayments of long-term debt and capital and financial leases for the years beginning January 1, 2017 and thereafter, are as follows (in millions): Long-term Capital and Financial Debt Lease Obligations Total 2017 $ — $ 4 $ 4 2018 — 4 4 2019 — 4 4 2020 — 4 4 2021 — 3 3 Thereafter 1,120 50 1,170 Total 1,120 69 1,189 Unamortized premium, discount and debt issuance cost (1 ) — (1 ) Amounts representing interest — (35 ) (35 ) Total $ 1,119 $ 34 $ 1,153
Nevada Power Company [Member]
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	Nevada Power 's long-term debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 General and refunding mortgage securities: 5.950% Series M, due 2016 — — 210 6.500% Series O, due 2018 324 324 323 6.500% Series S, due 2018 499 498 498 7.125% Series V, due 2019 500 499 499 6.650% Series N, due 2036 367 357 356 6.750% Series R, due 2037 349 345 345 5.375% Series X, due 2040 250 247 247 5.450% Series Y, due 2041 250 236 235 Variable-rate series (2016-1.890% to 1.928%, 2015-0.672% to 1.055%): Pollution Control Revenue Bonds Series 2006A, due 2032 38 38 38 Pollution Control Revenue Bonds Series 2006, due 2036 38 37 37 Capital and financial lease obligations - 2.750% to 11.600%, due through 2054 485 485 497 Total long-term debt and financial and capital leases $ 3,100 $ 3,066 $ 3,285 Reflected as: Current portion of long-term debt and financial and capital lease obligations $ 17 $ 225 Long-term debt and financial and capital lease obligations 3,049 3,060 Total long-term debt and financial and capital leases $ 3,066 $ 3,285
Maturities of Long-term Debt [Table Text Block]	The annual repayments of long-term debt and capital and financial leases for the years beginning January 1, 2017 and thereafter, are as follows (in millions): Long-term Capital and Financial Debt Lease Obligations Total 2017 $ — $ 75 $ 75 2018 823 74 897 2019 500 76 576 2020 — 75 75 2021 — 79 79 Thereafter 1,292 831 2,123 Total 2,615 1,210 3,825 Unamortized premium, discount and debt issuance cost (34 ) — (34 ) Executory costs — (111 ) (111 ) Amounts representing interest — (614 ) (614 ) Total $ 2,581 $ 485 $ 3,066
PacifiCorp [Member]
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	PacifiCorp's long-term debt and capital lease obligations were as follows as of December 31 (dollars in millions): 2016 2015 Average Average Principal Carrying Interest Carrying Interest Amount Value Rate Value Rate First mortgage bonds: 3.85% to 8.53%, due through 2021 $ 1,272 $ 1,269 5.10 % $ 1,271 5.10 % 2.95% to 8.27%, due 2022 to 2026 1,829 1,820 4.10 1,819 4.10 7.70% due 2031 300 298 7.70 298 7.70 5.25% to 6.10%, due 2034 to 2036 850 843 5.80 843 5.80 5.75% to 6.35%, due 2037 to 2039 2,150 2,134 6.00 2,133 6.00 4.10% due 2042 300 297 4.10 297 4.10 Variable-rate series, tax-exempt bond obligations (2016-0.69% to 0.86%; 2015-0.01% to 0.22%): Due 2017 to 2018 91 91 0.85 91 0.22 Due 2018 to 2025 (1) 108 108 0.74 107 0.01 Due 2024 (1)(2) 143 142 0.70 196 0.02 Due 2024 to 2025 (2) 50 50 0.80 59 0.21 Total long-term debt 7,093 7,052 7,114 Capital lease obligations: 8.75% to 14.61%, due through 2035 27 27 11.09 32 11.25 Total long-term debt and capital lease obligations $ 7,120 $ 7,079 $ 7,146 Reflected as: 2016 2015 Current portion of long-term debt and capital lease obligations $ 58 $ 68 Long-term debt and capital lease obligations 7,021 7,078 Total long-term debt and capital lease obligations $ 7,079 $ 7,146 1) Supported by $255 million and $310 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2016 and 2015 , respectively. 2) Secured by pledged first mortgage bonds registered to and held by the tax-exempt bond trustee generally with the same interest rates, maturity dates and redemption provisions as the tax-exempt bond obligations.
Maturities of Long-term Debt [Table Text Block]	As of December 31, 2016 , the annual principal maturities of long-term debt and total capital lease obligations for 2017 and thereafter are as follows (in millions): Long-term Capital Lease Debt Obligations Total 2017 $ 52 $ 9 $ 61 2018 586 4 590 2019 350 4 354 2020 38 3 41 2021 420 6 426 Thereafter 5,647 20 5,667 Total 7,093 46 7,139 Unamortized discount and debt issuance costs (41 ) — (41 ) Amounts representing interest — (19 ) (19 ) Total $ 7,052 $ 27 $ 7,079
NV Energy, Inc. [Member]
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	NV Energy NV Energy's long-term debt consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 NV Energy - 6.250% Senior Notes, due 2020 $ 315 $ 363 $ 373 Nevada Power: General and refunding mortgage securities: 5.950% Series M, due 2016 — — 210 6.500% Series O, due 2018 324 324 323 6.500% Series S, due 2018 499 498 498 7.125% Series V, due 2019 500 499 499 6.650% Series N, due 2036 367 357 356 6.750% Series R, due 2037 349 345 345 5.375% Series X, due 2040 250 247 247 5.450% Series Y, due 2041 250 236 235 Variable-rate series (2016-1.890% to 1.928%, 2015-0.672% to 1.055%): Pollution Control Revenue Bonds Series 2006A, due 2032 38 38 38 Pollution Control Revenue Bonds Series 2006, due 2036 38 37 37 Capital and financial lease obligations - 2.750% to 11.600%, due through 2054 485 485 497 Total Nevada Power 3,100 3,066 3,285 Sierra Pacific: General and refunding mortgage securities: 6.000% Series M, due 2016 — — 450 3.375% Series T, due 2023 250 248 248 2.600% Series U, due 2026 400 395 — 6.750% Series P, due 2037 252 255 255 Tax-exempt refunding revenue bond obligations: Fixed-rate series: 1.250% Pollution Control Series 2016A, due 2029 20 20 — 1.500% Gas Facilities Series 2016A, due 2031 58 58 — 3.000% Gas and Water Series 2016B, due 2036 60 64 — Variable-rate series (2016-0.788% to 0.800%, 2015-0.733% to 1.054%): Pollution Control Series 2006A, due 2031 — — 58 Pollution Control Series 2006B, due 2036 — — 74 Pollution Control Series 2006C, due 2036 — — 80 Water Facilities Series 2016C, due 2036 30 29 — Water Facilities Series 2016D, due 2036 25 25 — Water Facilities Series 2016E, due 2036 25 25 — Capital and financial lease obligations - 2.700% to 10.130%, due through 2054 34 34 37 Total Sierra Pacific 1,154 1,153 1,202 Total NV Energy $ 4,569 $ 4,582 $ 4,860
MidAmerican Funding [Member]
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	MidAmerican Funding MidAmerican Funding's long-term debt consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 MidAmerican Funding: 6.927% Senior Bonds, due 2029 $ 325 $ 291 $ 289 MidAmerican Energy: Tax-exempt bond obligations - Variable-rate tax-exempt bond obligation series: (2016-0.76%, 2015-0.03%), due 2023-2046 220 219 194 First Mortgage Bonds: 2.40%, due 2019 500 499 499 3.70%, due 2023 250 248 248 3.50%, due 2024 500 501 502 4.80%, due 2043 350 345 345 4.40%, due 2044 400 394 394 4.25%, due 2046 450 445 444 Notes: 5.95% Series, due 2017 250 250 250 5.3% Series, due 2018 350 350 349 6.75% Series, due 2031 400 396 395 5.75% Series, due 2035 300 298 298 5.8% Series, due 2036 350 347 347 Transmission upgrade obligation, 4.45% and 3.42% due through 2035 and 2036, respectively 10 7 4 Capital lease obligations - 4.16%, due through 2020 2 2 2 Total MidAmerican Energy 4,332 4,301 4,271 Total MidAmerican Funding $ 4,657 $ 4,592 $ 4,560
Northern Powergrid Holdings [Member]
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	Northern Powergrid Northern Powergrid and its subsidiaries' long-term debt consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value (1) 2016 2015 8.875% Bonds, due 2020 $ 123 $ 136 $ 162 9.25% Bonds, due 2020 247 259 315 3.901% to 4.586% European Investment Bank loans, due 2018 to 2022 333 333 398 7.25% Bonds, due 2022 247 257 306 2.50% Bonds due 2025 185 182 217 2.073% European Investment Bank loan, due 2025 62 62 — 2.564% European Investment Bank loans, due 2027 308 308 368 7.25% Bonds, due 2028 229 234 280 4.375% Bonds, due 2032 185 182 217 5.125% Bonds, due 2035 247 243 291 5.125% Bonds, due 2035 185 183 218 Total Northern Powergrid $ 2,351 $ 2,379 $ 2,772 (1) The par values for these debt instruments are denominated in sterling.
BHE Pipeline Group [Member]
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	BHE Pipeline Group ' long-term debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 Northern Natural Gas: 5.75% Senior Notes, due 2018 $ 200 $ 199 $ 199 4.25% Senior Notes, due 2021 200 199 199 5.8% Senior Bonds, due 2037 150 149 149 4.1% Senior Bonds, due 2042 250 248 248 Total Northern Natural Gas 800 795 795 Kern River: 4.893% Senior Notes, due 2018 195 195 245 Total BHE Pipeline Group $ 995 $ 990 $ 1,040
PacifiCorp [Member]
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	PacifiCorp PacifiCorp's long-term debt consists of the following, including unamortized premiums, discounts and debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 First mortgage bonds: 3.85% to 8.53%, due through 2021 $ 1,272 $ 1,269 $ 1,271 2.95% to 8.27%, due 2022 to 2026 1,829 1,820 1,819 7.70% due 2031 300 298 298 5.25% to 6.10%, due 2034 to 2036 850 843 843 5.75% to 6.35%, due 2037 to 2039 2,150 2,134 2,133 4.10% due 2042 300 297 297 Variable-rate series, tax-exempt bond obligations (2016-0.69% to 0.86%; 2015-0.01% to 0.22%): Due 2017 to 2018 91 91 91 Due 2018 to 2025 (1) 108 108 107 Due 2024 (1)(2) 143 142 196 Due 2024 to 2025 (2) 50 50 59 Capital lease obligations - 8.75% to 14.61%, due through 2035 27 27 45 Total PacifiCorp $ 7,120 $ 7,079 $ 7,159 (1) Supported by $255 million and $310 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2016 and 2015 , respectively. (2) Secured by pledged first mortgage bonds registered to and held by the tax-exempt bond trustee generally with the same interest rates, maturity dates and redemption provisions as the tax-exempt bond obligations.
BHE Renewables [Member]
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	BHE Renewables BHE Renewables ' long-term debt consists of the following, including fair value adjustments and unamortized debt issuance costs, as of December 31 (dollars in millions): Par Value 2016 2015 Fixed-rate (1) : CE Generation Bonds, 7.416%, due 2018 $ 67 $ 67 $ 97 Salton Sea Funding Corporation Bonds, 7.475%, due 2018 30 31 51 Cordova Funding Corporation Bonds, 8.48% to 9.07%, due 2019 96 97 113 Bishop Hill Holdings Senior Notes, 5.125%, due 2032 100 99 102 Solar Star Funding Senior Notes, 3.950%, due 2035 316 311 321 Solar Star Funding Senior Notes, 5.375%, due 2035 977 966 988 Grande Prairie Wind Senior Notes, 3.860%, due 2037 419 414 — Topaz Solar Farms Senior Notes, 5.750%, due 2039 791 780 815 Topaz Solar Farms Senior Notes, 4.875%, due 2039 230 229 239 Other 22 22 25 Variable-rate (1) : Pinyon Pines I and II Term Loans, due 2019 (2) 356 355 378 Wailuku Special Purpose Revenue Bonds, 0.90%, due 2021 7 7 8 TX Jumbo Road Term Loan, due 2025 (2) 212 206 219 Marshall Wind Term Loan, due 2026 (2) 93 90 — Total BHE Renewables $ 3,716 $ 3,674 $ 3,356 (1) Amortizes quarterly or semiannually. (2) The term loans have variable interest rates based on LIBOR plus a margin that varies during the terms of the agreements. The Company has entered into interest rate swaps that fix the interest rate on 75% of the Pinyon Pines outstanding debt and 100% of the TX Jumbo Road and Marshall Wind outstanding debt. The variable interest rate as of December 31, 2016 and 2015 was 2.62% and 2.23% , respectively, while the fixed interest rates ranged from 3.21% to 3.63% as of December 31, 2016 , and 3.55% to 3.63% as of December 31, 2015 .
BHE Transmission [Member]
Debt Instrument [Line Items]
Subsidiary Debt [Table Text Block]	BHE Transmission 's long-term debt consists of the following, including fair value adjustments and unamortized premiums, discounts and debt issuance costs, as of December 31, (dollars in millions): Par Value (1) 2016 2015 AltaLink Investments, L.P.: Series 09-1 Senior Bonds, 5.207%, due 2016 $ — $ — $ 112 Series 12-1 Senior Bonds, 3.674%, due 2019 149 153 151 Series 13-1 Senior Bonds, 3.265%, due 2020 149 152 149 Series 15-1 Senior Bonds, 2.244%, due 2022 149 148 144 Total AltaLink Investments, L.P. 447 453 556 AltaLink, L.P.: Series 2008-1 Notes, 5.243%, due 2018 149 148 145 Series 2013-2 Notes, 3.621%, due 2020 93 93 90 Series 2012-2 Notes, 2.978%, due 2022 204 204 198 Series 2013-4 Notes, 3.668%, due 2023 372 371 360 Series 2014-1 Notes, 3.399%, due 2024 260 260 252 Series 2016-1 Notes, 2.747%, due 2026 260 259 — Series 2006-1 Notes, 5.249%, due 2036 112 111 108 Series 2010-1 Notes, 5.381%, due 2040 93 93 90 Series 2010-2 Notes, 4.872%, due 2040 112 111 108 Series 2011-1 Notes, 4.462%, due 2041 205 204 198 Series 2012-1 Notes, 3.99%, due 2042 391 385 374 Series 2013-3 Notes, 4.922%, due 2043 260 260 252 Series 2014-3 Notes, 4.054%, due 2044 219 218 212 Series 2015-1 Notes, 4.090%, due 2045 260 259 251 Series 2016-2 Notes, 3.717%, due 2046 335 333 — Series 2013-1 Notes, 4.446%, due 2053 186 186 180 Series 2014-2 Notes, 4.274%, due 2064 97 97 93 Total AltaLink, L.P. 3,608 3,592 2,911 Other: Construction Loan, 4.950%, due 2021 13 13 — Total BHE Transmission $ 4,068 $ 4,058 $ 3,467 (1) The par values for these debt instruments are denominated in Canadian dollars.

Risk Management and Hedging A52

Risk Management and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	The following table, which reflects master netting arrangements and excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of the Company's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Consolidated Balance Sheets (in millions): Other Other Other Current Other Current Long-term Assets Assets Liabilities Liabilities Total As of December 31, 2016: Not designated as hedging contracts: Commodity assets (1) $ 42 $ 86 $ 5 $ 2 $ 135 Commodity liabilities (1) (10 ) — (46 ) (150 ) (206 ) Interest rate assets 15 — — — 15 Interest rate liabilities — — (4 ) (6 ) (10 ) Total 47 86 (45 ) (154 ) (66 ) Designated as hedging contracts: Commodity assets 1 — 2 3 6 Commodity liabilities — — (14 ) (8 ) (22 ) Interest rate assets — 8 — — 8 Interest rate liabilities — — (3 ) — (3 ) Total 1 8 (15 ) (5 ) (11 ) Total derivatives 48 94 (60 ) (159 ) (77 ) Cash collateral receivable — — 13 61 74 Total derivatives - net basis $ 48 $ 94 $ (47 ) $ (98 ) $ (3 ) As of December 31, 2015: Not designated as hedging contracts: Commodity assets (1) $ 25 $ 72 $ 7 $ 2 $ 106 Commodity liabilities (1) (4 ) — (113 ) (175 ) (292 ) Interest rate assets 7 — — — 7 Interest rate liabilities — — (3 ) (6 ) (9 ) Total 28 72 (109 ) (179 ) (188 ) Designated as hedging contracts: Commodity assets — — 1 2 3 Commodity liabilities — — (33 ) (17 ) (50 ) Interest rate assets — 3 — — 3 Interest rate liabilities — — (4 ) (1 ) (5 ) Total — 3 (36 ) (16 ) (49 ) Total derivatives 28 75 (145 ) (195 ) (237 ) Cash collateral receivable — — 40 63 103 Total derivatives - net basis $ 28 $ 75 $ (105 ) $ (132 ) $ (134 ) (1) The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31, 2016 and 2015 , a net regulatory asset of $148 million and $250 million , respectively, was recorded related to the net derivative liability of $71 million and $186 million , respectively. The difference between the net regulatory asset and the net derivative liability relates primarily to a power purchase agreement derivative at BHE Renewables.
Schedule of Regulatory Assets (Liabilities), Net, Unrealized Loss (Gain), Net, on Derivative Contracts [Table Text Block]	The following table reconciles the beginning and ending balances of the Company's net regulatory assets and summarizes the pre-tax gains and losses on commodity derivative contracts recognized in net regulatory assets, as well as amounts reclassified to earnings for the years ended December 31 (in millions): Commodity Derivatives 2016 2015 2014 Beginning balance $ 250 $ 223 $ 182 Changes in fair value recognized in net regulatory assets (30 ) 128 96 Net (losses) gains reclassified to operating revenue (5 ) 1 (32 ) Net losses reclassified to cost of sales (67 ) (102 ) (23 ) Ending balance $ 148 $ 250 $ 223
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) [Table Text Block]	Certain commodity derivative contracts have settled and the fair value at the date of settlement remains in AOCI and is recognized in earnings when the forecasted transactions impact earnings. The following table reconciles the beginning and ending balances of the Company's AOCI (pre-tax) and summarizes pre-tax gains and losses on commodity derivative contracts designated and qualifying as cash flow hedges recognized in OCI, as well as amounts reclassified to earnings for the years ended December 31 (in millions): Commodity Derivatives 2016 2015 2014 Beginning balance $ 46 $ 32 $ 12 Changes in fair value recognized in OCI 26 52 (6 ) Net gains reclassified to operating revenue 1 9 — Net (losses) gains reclassified to cost of sales (57 ) (47 ) 26 Ending balance $ 16 $ 46 $ 32
Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]	The following table summarizes the net notional amounts of outstanding derivative contracts with fixed price terms that comprise the mark-to-market values as of December 31 (in millions): Unit of Measure 2016 2015 Electricity purchases Megawatt hours 5 10 Natural gas purchases Decatherms 271 317 Fuel purchases Gallons 11 11 Interest rate swaps US$ 714 653 Mortgage commitments, net US$ (309 ) (312 )
PacifiCorp [Member]
Derivative [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	The following table, which reflects master netting arrangements and excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of PacifiCorp's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Consolidated Balance Sheets (in millions): Other Other Other Current Other Current Long-term Assets Assets Liabilities Liabilities Total As of December 31, 2016: Not designated as hedging contracts (1) : Commodity assets $ 24 $ 2 $ 1 $ — $ 27 Commodity liabilities (6 ) — (14 ) (84 ) (104 ) Total 18 2 (13 ) (84 ) (77 ) Total derivatives 18 2 (13 ) (84 ) (77 ) Cash collateral receivable — — 10 59 69 Total derivatives - net basis $ 18 $ 2 $ (3 ) $ (25 ) $ (8 ) As of December 31, 2015: Not designated as hedging contracts (1) : Commodity assets $ 10 $ — $ 2 $ — $ 12 Commodity liabilities (1 ) — (58 ) (89 ) (148 ) Total 9 — (56 ) (89 ) (136 ) Total derivatives 9 — (56 ) (89 ) (136 ) Cash collateral receivable — — 18 57 75 Total derivatives - net basis $ 9 $ — $ (38 ) $ (32 ) $ (61 ) (1) PacifiCorp's commodity derivatives are generally included in rates and as of December 31, 2016 and 2015 , a regulatory asset of $73 million and $133 million , respectively, was recorded related to the net derivative liability of $77 million and $136 million , respectively.
Schedule of Regulatory Assets (Liabilities), Net, Unrealized Loss (Gain), Net, on Derivative Contracts [Table Text Block]	The following table reconciles the beginning and ending balances of PacifiCorp's regulatory assets and summarizes the pre-tax gains and losses on commodity derivative contracts recognized in regulatory assets, as well as amounts reclassified to earnings for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 133 $ 85 $ 55 Changes in fair value recognized in regulatory assets (27 ) 82 45 Net gains reclassified to operating revenue 10 40 (4 ) Net losses reclassified to energy costs (43 ) (74 ) (11 ) Ending balance $ 73 $ 133 $ 85
Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]	The following table summarizes the net notional amounts of outstanding commodity derivative contracts with fixed price terms that comprise the mark-to-market values as of December 31 (in millions): Unit of Measure 2016 2015 Electricity (sales) purchases Megawatt hours (3 ) 1 Natural gas purchases Decatherms 84 111 Fuel oil purchases Gallons 11 11
MidAmerican Energy Company [Member]
Derivative [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	The following table, which reflects master netting arrangements and excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of MidAmerican Energy's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Balance Sheets (in millions): Other Other Other Current Other Current Long-term Assets Assets Liabilities Liabilities Total As of December 31, 2016: Not designated as hedging contracts (1)(2) : Commodity assets $ 8 $ 2 $ — $ — $ 10 Commodity liabilities (2 ) — (3 ) (1 ) (6 ) Total 6 2 (3 ) (1 ) 4 Designated as hedging contracts (2) : Commodity assets — — — — — Commodity liabilities — — — — — Total — — — — — Total derivatives 6 2 (3 ) (1 ) 4 Cash collateral receivable — — 1 — 1 Total derivatives - net basis $ 6 $ 2 $ (2 ) $ (1 ) $ 5 As of December 31, 2015: Not designated as hedging contracts (1) : Commodity assets $ 12 $ 4 $ 5 $ 2 $ 23 Commodity liabilities (3 ) — (36 ) (10 ) (49 ) Total 9 4 (31 ) (8 ) (26 ) Designated as hedging contracts: Commodity assets — — 1 2 3 Commodity liabilities — — (32 ) (17 ) (49 ) Total — — (31 ) (15 ) (46 ) Total derivatives 9 4 (62 ) (23 ) (72 ) Cash collateral receivable — — 22 6 28 Total derivatives - net basis $ 9 $ 4 $ (40 ) $ (17 ) $ (44 ) (1) MidAmerican Energy's commodity derivatives not designated as hedging contracts are generally included in regulated rates. Accordingly, as of December 31, 2016 , a net regulatory liability of $4 million was recorded related to the net derivative asset of $4 million , and as of December 31, 2015 , a net regulatory asset of $20 million was recorded related to the net derivative liability of $26 million . (2) The changes in derivative values from December 31, 2015, are substantially due to the transfer of MidAmerican Energy's unregulated retail services business to a subsidiary of BHE.
Schedule of Regulatory Assets (Liabilities), Net, Unrealized Loss (Gain), Net, on Derivative Contracts [Table Text Block]	The following table reconciles the beginning and ending balances of MidAmerican Energy's net regulatory assets (liabilities) and summarizes the pre-tax gains and losses on commodity derivative contracts recognized in net regulatory assets (liabilities), as well as amounts reclassified to earnings for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 20 $ 38 $ 10 Changes in fair value recognized in net regulatory assets (liabilities) 3 40 61 Net losses reclassified to operating revenue (15 ) (42 ) (28 ) Net losses reclassified to cost of fuel, energy and capacity — (1 ) (1 ) Net losses reclassified to cost of gas sold (12 ) (15 ) (4 ) Ending balance $ (4 ) $ 20 $ 38
Schedule Of Nonregulated Derivatives Not Designated As Hedging Instruments Gain (Loss) In Statement Of Financial Performance [Table Text Block]	The following table summarizes the pre-tax unrealized gains (losses) included on the Statements of Operations associated with MidAmerican Energy's derivative contracts not designated as hedging contracts and not recorded as a net regulatory asset or liability for the years ended December 31 (in millions): 2016 2015 2014 Nonregulated operating revenue $ — $ 15 $ 6 Regulated cost of fuel, energy and capacity — 2 — Nonregulated cost of sales — (21 ) 9 Total $ — $ (4 ) $ 15
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) [Table Text Block]	The following table reconciles the beginning and ending balances of MidAmerican Energy's accumulated other comprehensive loss (pre-tax) and summarizes pre-tax gains and losses on derivative contracts designated and qualifying as cash flow hedges recognized in OCI, as well as amounts reclassified to earnings, for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ 45 $ 34 $ 11 Transfer to affiliate (45 ) — — Changes in fair value recognized in OCI — 58 (3 ) Net (losses) gains reclassified to nonregulated cost of sales — (47 ) 26 Ending balance $ — $ 45 $ 34
Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]	The following table summarizes the net notional amounts of outstanding derivative contracts with fixed price terms that comprise the mark-to-market values as of December 31 (in millions): Unit of Measure 2016 2015 Electricity purchases Megawatt hours — 15 Natural gas purchases Decatherms 18 17
Nevada Power Company [Member]
Derivative [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	The following table, which excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of Nevada Power 's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Consolidated Balance Sheets (in millions): Other Other Current Long-term Liabilities Liabilities Total As of December 31, 2016: Commodity derivative liabilities (1) $ (7 ) $ (7 ) $ (14 ) As of December 31, 2015: Commodity derivative liabilities (1) $ (8 ) $ (14 ) $ (22 ) (1) Nevada Power 's commodity derivatives not designated as hedging contracts are included in regulated rates and as of December 31 , 2016 and 2015 , a regulatory asset of $14 million and $22 million , respectively, was recorded related to the derivative liability of $14 million and $22 million , respectively.
Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]	The following table summarizes the net notional amounts of outstanding derivative contracts with indexed and fixed price terms that comprise the mark-to-market values as of December 31 (in millions): Unit of Measure 2016 2015 Electricity sales Megawatt hours (2 ) (2 ) Natural gas purchases Decatherms 114 126

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Assets and Liabilities Net Measured On Recurring Basis Unobservable Input Reconciliation [Table Text Block]	The following table reconciles the beginning and ending balances of the Company's assets and liabilities measured at fair value on a recurring basis using significant Level 3 inputs for the years ended December 31 (in millions): Commodity Derivatives Interest Rate Derivatives Auction Rate Securities 2016 2015 2014 2016 2015 2014 2016 2015 2014 Beginning balance $ 47 $ 51 $ 60 $ 4 $ — $ — $ 44 $ 45 $ 44 Changes included in earnings 8 19 19 121 87 — 5 — — Changes in fair value recognized in OCI (2 ) (7 ) — — — — 8 (1 ) 1 Changes in fair value recognized in net regulatory assets (11 ) (19 ) 5 — — — — — — Purchases 1 1 1 — — — — — — Redemptions — — — — — — (57 ) — — Settlements 17 2 1 (119 ) (86 ) — — — — Transfers from Level 2 — — (35 ) — 3 — — — — Ending balance $ 60 $ 47 $ 51 $ 6 $ 4 $ — $ — $ 44 $ 45
Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following table presents the Company's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Other (1) Total As of December 31, 2016: Assets: Commodity derivatives $ 5 $ 49 $ 87 $ (22 ) $ 119 Interest rate derivatives — 16 7 — 23 Mortgage loans held for sale — 359 — — 359 Money market mutual funds (2) 586 — — — 586 Debt securities: United States government obligations 161 — — — 161 International government obligations — 3 — — 3 Corporate obligations — 36 — — 36 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Equity securities: United States companies 250 — — — 250 International companies 1,190 — — — 1,190 Investment funds 147 — — — 147 $ 2,339 $ 467 $ 94 $ (22 ) $ 2,878 Liabilities: Commodity derivatives $ (2 ) $ (199 ) $ (27 ) $ 96 $ (132 ) Interest rate derivatives (1 ) (11 ) (1 ) — (13 ) $ (3 ) $ (210 ) $ (28 ) $ 96 $ (145 ) As of December 31, 2015: Assets: Commodity derivatives $ — $ 16 $ 93 $ (16 ) $ 93 Interest rate derivatives — 5 5 — 10 Mortgage loans held for sale — 327 — — 327 Money market mutual funds (2) 421 — — — 421 Debt securities: United States government obligations 133 — — — 133 International government obligations — 2 — — 2 Corporate obligations — 39 — — 39 Municipal obligations — 1 — — 1 Agency, asset and mortgage-backed obligations — 3 — — 3 Auction rate securities — — 44 — 44 Equity securities: United States companies 239 — — — 239 International companies 1,244 — — — 1,244 Investment funds 136 — — — 136 $ 2,173 $ 393 $ 142 $ (16 ) $ 2,692 Liabilities: Commodity derivatives $ (13 ) $ (283 ) $ (46 ) $ 119 $ (223 ) Interest rate derivatives — (13 ) (1 ) — (14 ) $ (13 ) $ (296 ) $ (47 ) $ 119 $ (237 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $74 million and $103 million as of December 31, 2016 and 2015 , respectively. (2) Amounts are included in cash and cash equivalents; other current assets; and noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
Fair Value, by Balance Sheet Grouping [Table Text Block]	The following table presents the carrying value and estimated fair value of the Company's long-term debt as of December 31 (in millions): 2016 2015 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 36,116 $ 40,718 $ 37,972 $ 41,785
Nevada Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following table presents Nevada Power 's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Total As of December 31, 2016: Assets: Money market mutual funds (1) $ 220 $ — $ — $ 220 Investment funds 6 — — 6 $ 226 $ — $ — $ 226 Liabilities - commodity derivatives $ — $ — $ (14 ) $ (14 ) As of December 31, 2015: Assets - investment funds $ 5 $ — $ — $ 5 Liabilities - commodity derivatives $ — $ — $ (22 ) $ (22 )
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]	The following table reconciles the beginning and ending balances of Nevada Power 's commodity derivative liabilities measured at fair value on a recurring basis using significant Level 3 inputs for the years ended December 31 (in millions): 2016 2015 2014 Beginning balance $ (22 ) $ (30 ) $ (47 ) Changes in fair value recognized in regulatory assets (4 ) — 9 Settlements 12 8 8 Ending balance $ (14 ) $ (22 ) $ (30 )
Fair Value, by Balance Sheet Grouping [Table Text Block]	The following table presents the carrying value and estimated fair value of Nevada Power 's long-term debt as of December 31 (in millions): 2016 2015 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 2,581 $ 3,040 $ 2,788 $ 3,240
PacifiCorp [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following table presents the fair value of plan assets, by major category, for PacifiCorp's defined benefit pension plan (in millions): Input Levels for Fair Value Measurements Level 1 (1) Level 2 (1) Level 3 (1) Total As of December 31, 2016: Cash equivalents $ — $ 10 $ — $ 10 Debt securities: United States government obligations 25 — — 25 Corporate obligations — 36 — 36 Municipal obligations — 6 — 6 Agency, asset and mortgage-backed obligations — 37 — 37 Equity securities: United States companies 389 — — 389 International companies 15 — — 15 Investment funds (2) 83 — — 83 Total assets in the fair value hierarchy $ 512 $ 89 $ — 601 Investment funds (2) measured at net asset value 337 Limited partnership interests (3) measured at net asset value 61 Investments at fair value $ 999 As of December 31, 2015: Cash equivalents $ — $ 10 $ — $ 10 Debt securities: United States government obligations 19 — — 19 Corporate obligations — 42 — 42 Municipal obligations — 5 — 5 Agency, asset and mortgage-backed obligations — 43 — 43 Equity securities: United States companies 408 — — 408 International companies 17 — — 17 Investment funds (2) 83 — — 83 Total assets in the fair value hierarchy $ 527 $ 100 $ — 627 Investment funds (2) measured at net asset value 351 Limited partnership interests (3) measured at net asset value 65 Investments at fair value $ 1,043 (1) Refer to Note 12 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are substantially comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 54% and 46% respectively, for 2016 and 53% and 47% , respectively, for 2015 , and are invested in United States and international securities of approximately 39% and 61% , respectively, for 2016 and 40% and 60% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. The following table presents the fair value of plan assets, by major category, for PacifiCorp's defined benefit other postretirement plan (in millions): Input Levels for Fair Value Measurements Level 1 (1) Level 2 (1) Level 3 (1) Total As of December 31, 2016: Cash and cash equivalents $ 4 $ 1 $ — $ 5 Debt securities: United States government obligations 11 — — 11 Corporate obligations — 13 — 13 Municipal obligations — 2 — 2 Agency, asset and mortgage-backed obligations — 13 — 13 Equity securities: United States companies 93 — — 93 International companies 4 — — 4 Investment funds (2) 32 — — 32 Total assets in the fair value hierarchy $ 144 $ 29 $ — 173 Investment funds (2) measured at net asset value 125 Limited partnership interests (3) measured at net asset value 4 Investments at fair value $ 302 As of December 31, 2015: Cash and cash equivalents $ 4 $ 1 $ — $ 5 Debt securities: United States government obligations 9 — — 9 Corporate obligations — 15 — 15 Municipal obligations — 1 — 1 Agency, asset and mortgage-backed obligations — 14 — 14 Equity securities: United States companies 95 — — 95 International companies 4 — — 4 Investment funds (2) 32 — — 32 Total assets in the fair value hierarchy $ 144 $ 31 $ — 175 Investment funds (2) measured at net asset value 126 Limited partnership interests (3) measured at net asset value 4 Investments at fair value $ 305 (1) Refer to Note 12 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are substantially comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 62% and 38% , respectively, for 2016 and 61% and 39% , respectively, for 2015 , and are invested in United States and international securities of approximately 71% and 29% , respectively, for 2016 and 67% and 33% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. The following table presents PacifiCorp's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Other (1) Total As of December 31, 2016: Assets: Commodity derivatives $ — $ 27 $ — $ (7 ) $ 20 Money market mutual funds (2) 13 — — — 13 Investment funds 17 — — — 17 $ 30 $ 27 $ — $ (7 ) $ 50 Liabilities - Commodity derivatives $ — $ (104 ) $ — $ 76 $ (28 ) As of December 31, 2015: Assets: Commodity derivatives $ — $ 9 $ 3 $ (3 ) $ 9 Money market mutual funds (2) 13 — — — 13 Investment funds 15 — — — 15 $ 28 $ 9 $ 3 $ (3 ) $ 37 Liabilities - Commodity derivatives $ — $ (148 ) $ — $ 78 $ (70 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $69 million and $75 million as of December 31, 2016 and 2015 , respectively. (2) Amounts are included in cash and cash equivalents, other current assets and other assets on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
Fair Value, by Balance Sheet Grouping [Table Text Block]	The following table presents the carrying value and estimated fair value of PacifiCorp's long-term debt as of December 31 (in millions): 2016 2015 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 7,052 $ 8,204 $ 7,114 $ 8,210
MidAmerican Energy Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following table presents the fair value of plan assets, by major category, for MidAmerican Energy's defined benefit pension plan (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ — $ 17 $ — $ 17 Debt securities: United States government obligations 9 — — 9 Corporate obligations — 53 — 53 Municipal obligations — 6 — 6 Agency, asset and mortgage-backed obligations — 22 — 22 Equity securities: United States companies 130 — — 130 International equity securities 39 — — 39 Investment funds (2) 63 — — 63 Total assets in the hierarchy $ 241 $ 98 $ — 339 Investment funds (2) measured at net asset value 295 Real estate funds measured at net asset value 50 Total assets measured at fair value $ 684 As of December 31, 2015: Cash equivalents $ — $ 16 $ — $ 16 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 57 — 57 Municipal obligations — 6 — 6 Agency, asset and mortgage-backed obligations — 27 — 27 Equity securities: United States companies 130 — — 130 International equity securities 40 — — 40 Investment funds (2) 61 — — 61 Total assets in the hierarchy $ 236 $ 106 $ — 342 Investment funds (2) measured at net asset value 296 Real estate funds measured at net asset value 40 Total assets measured at fair value $ 678 (1) Refer to Note 14 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 74% and 26% , respectively, for 2016 and 72% and 28% , respectively, for 2015 . Additionally, these funds are invested in United States and international securities of approximately 71% and 29% , respectively, for 2016 and 73% and 27% , respectively, for 2015 . The following table presents the fair value of plan assets, by major category, for MidAmerican Energy's defined benefit other postretirement plans (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 10 $ — $ — $ 10 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 11 — 11 Municipal obligations — 37 — 37 Agency, asset and mortgage-backed obligations — 11 — 11 Equity securities: United States companies 122 — — 122 Investment funds (2) 56 — — 56 Total assets measured at fair value $ 193 $ 59 $ — $ 252 As of December 31, 2015: Cash equivalents $ 5 $ — $ — $ 5 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 12 — 12 Municipal obligations — 39 — 39 Agency, asset and mortgage-backed obligations — 12 — 12 Equity securities: United States companies 120 — — 120 Investment funds (2) 56 — — 56 Total assets measured at fair value $ 186 $ 63 $ — $ 249 (1) Refer to Note 14 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 70% and 30% , respectively, for 2016 and 68% and 32% , respectively, for 2015 . Additionally, these funds are invested in United States and international securities of approximately 30% and 70% , respectively, for 2016 and 32% and 68% , respectively, for 2015 . The following table presents MidAmerican Energy's assets and liabilities recognized on the Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Other (1) Total As of December 31, 2016: Assets: Commodity derivatives $ — $ 9 $ 1 $ (2 ) $ 8 Money market mutual funds (2) 1 — — — 1 Debt securities: United States government obligations 161 — — — 161 International government obligations — 3 — — 3 Corporate obligations — 36 — — 36 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Equity securities: United States companies 250 — — — 250 International companies 5 — — — 5 Investment funds 9 — — — 9 $ 426 $ 52 $ 1 $ (2 ) $ 477 Liabilities - commodity derivatives $ — $ (3 ) $ (3 ) $ 3 $ (3 ) As of December 31, 2015 Assets: Commodity derivatives $ — $ 8 $ 18 $ (13 ) $ 13 Money market mutual funds (2) 56 — — — 56 Debt securities: United States government obligations 133 — — — 133 International government obligations — 2 — — 2 Corporate obligations — 39 — — 39 Municipal obligations — 1 — — 1 Agency, asset and mortgage-backed obligations — 3 — — 3 Auction rate securities — — 26 — 26 Equity securities: United States companies 239 — — — 239 International companies 6 — — — 6 Investment funds 4 — — — 4 $ 438 $ 53 $ 44 $ (13 ) $ 522 Liabilities - commodity derivatives $ (13 ) $ (61 ) $ (24 ) $ 41 $ (57 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $1 million and $28 million as of December 31, 2016 and 2015 , respectively. (2) Amounts are included in cash and cash equivalents and investments and restricted cash and investments on the Balance Sheets. The fair value of these money market mutual funds approximates cost.
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]	The following table reconciles the beginning and ending balances of MidAmerican Energy's assets measured at fair value on a recurring basis using significant Level 3 inputs for the years ended December 31 (in millions): Commodity Derivatives Auction Rate Securities 2016 2015 2014 2016 2015 2014 Beginning balance $ (6 ) $ 12 $ (3 ) $ 26 $ 26 $ 23 Transfer to affiliate (4 ) — — — — — Changes included in earnings (1) — 11 12 5 — — Changes in fair value recognized in OCI — (7 ) — 4 — 3 Changes in fair value recognized in net regulatory assets (6 ) (25 ) 6 — — — Purchases — 1 1 — — — Redemptions — — — (35 ) — — Settlements 14 2 (4 ) — — — Ending balance $ (2 ) $ (6 ) $ 12 $ — $ 26 $ 26 (1) Changes included in earnings related to MidAmerican Energy's unregulated retail services business that was transferred to an affiliate of BHE. Refer to Note 3 for a discussion of discontinued operations. Net unrealized (losses) gains included in earnings for the years ended December 31, 2015 and 2014 , related to commodity derivatives held at December 31, 2015 and 2014 , totaled $8 million and $16 million , respectively.
Fair Value, by Balance Sheet Grouping [Table Text Block]	The following table presents the carrying value and estimated fair value of MidAmerican Energy's long-term debt as of December 31, (in millions): 2016 2015 Carrying Value Fair Value Carrying Value Fair Value Long-term debt $ 4,301 $ 4,735 $ 4,271 $ 4,636
MidAmerican Funding, LLC and Subsidiaries [Domain]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, by Balance Sheet Grouping [Table Text Block]	The following table presents the carrying value and estimated fair value of MidAmerican Funding's long-term debt as of December 31 (in millions): 2016 2015 Carrying Value Fair Value Carrying Value Fair Value Long-term debt $ 4,627 $ 5,164 $ 4,597 $ 5,051
Sierra Pacific Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following table presents Sierra Pacific 's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Total As of December 31, 2016: Assets: Money market mutual funds (1) $ 35 $ — $ — $ 35 Investment funds 1 — — 1 $ 36 $ — $ — $ 36 As of December 31, 2015: Assets - investment funds $ 1 $ — $ — $ 1 Liabilities - commodity derivatives $ — $ — $ (1 ) $ (1 ) (1) Amounts are included in cash and cash equivalents on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
Fair Value, by Balance Sheet Grouping [Table Text Block]	The following table presents the carrying value and estimated fair value of Sierra Pacific 's long-term debt as of December 31 (in millions): 2016 2015 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 1,119 $ 1,191 $ 1,165 $ 1,248

Other, Net (Tables)

Other, Net (Tables)	12 Months Ended
	Dec. 31, 2016
MidAmerican Energy Company [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Schedule of Other Nonoperating Income (Expense) [Table Text Block]	Other, net, as shown on the Statements of Operations, includes the following other income (expense) items for the years ended December 31 (in millions): 2016 2015 2014 Corporate-owned life insurance income $ 8 $ 4 $ 8 Gain on redemption of auction rate securities 5 — — Other, net 1 1 2 Total $ 14 $ 5 $ 10
MidAmerican Funding, LLC and Subsidiaries [Domain]
Component of Other Income (Expense), Nonoperating [Line Items]
Schedule of Other Nonoperating Income (Expense) [Table Text Block]	as shown on the Consolidated Statements of Operations, includes the following other income (expense) items for the years ended December 31 (in millions): 2016 2015 2014 Corporate-owned life insurance income $ 8 $ 4 $ 8 Gain on redemption of auction rate securities 5 — — Gains on sales of assets and other investments 3 13 — Leveraged leases — 1 5 Other, net 3 1 5 Total $ 19 $ 19 $ 18 MidAmerican Funding recognized a $13 million pre-tax gain on the sale of an investment in a generating facility lease in 2015.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Components of Income Tax Expense (Benefit) [Table Text Block]	Income tax expense (benefit) consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Current: Federal $ (743 ) $ (929 ) $ (1,872 ) State 1 29 (3 ) Foreign 55 84 129 (687 ) (816 ) (1,746 ) Deferred: Federal 1,164 1,310 2,296 State (59 ) (53 ) 37 Foreign (7 ) 17 11 1,098 1,274 2,344 Investment tax credits (8 ) (8 ) (9 ) Total $ 403 $ 450 $ 589
Effective Income Tax Rate Reconciliation [Table Text Block]	A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income before income tax expense is as follows for the years ended December 31: 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (14 ) (11 ) (10 ) State income tax, net of federal income tax benefit (1 ) (1 ) 1 Income tax effect of foreign income (6 ) (7 ) (3 ) Equity income 2 2 2 Other, net (2 ) (2 ) (2 ) Effective income tax rate 14 % 16 % 23 %
Components of Net Deferred Income Tax Liability [Table Text Block]	The net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Federal, state and foreign carryforwards $ 987 $ 865 Regulatory liabilities 909 834 AROs 326 317 Employee benefits 209 190 Derivative contracts 29 83 Other 707 815 Total deferred income tax assets 3,167 3,104 Valuation allowances (64 ) (35 ) Total deferred income tax assets, net 3,103 3,069 Deferred income tax liabilities: Property-related items (14,237 ) (13,157 ) Regulatory assets (1,449 ) (1,446 ) Investments (962 ) (852 ) Other (334 ) (299 ) Total deferred income tax liabilities (16,982 ) (15,754 ) Net deferred income tax liability $ (13,879 ) $ (12,685 )
Summary of Operating Loss Carryforwards [Table Text Block]	The following table provides the Company's net operating loss and tax credit carryforwards and expiration dates as of December 31, 2016 (in millions): Federal State Foreign Total Net operating loss carryforwards (1) $ 179 $ 11,549 $ 352 $ 12,080 Deferred income taxes on net operating loss carryforwards $ 65 $ 674 $ 95 $ 834 Expiration dates 2023-2025 2017-2036 2035-2036 Tax credits (2) $ 128 $ 25 $ — $ 153 Expiration dates 2023- indefinite 2017- indefinite (1) The federal net operating loss carry forwards relate principally to net operating loss carry forwards of subsidiaries that are tax residents in both the United States and the United Kingdom. The federal net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2023. (2) Includes $97 million of deferred foreign tax credits associated with the federal income tax on unremitted tax earnings and profit pools that will begin to be creditable and expire 10 years after the date the foreign earnings are repatriated through actual or deemed dividends. As of December 31, 2016 the statute of limitation had not begun on the foreign tax credit carryforwards.
Net Unrecognized Tax Benefits Roll Forward [Table Text Block]	A reconciliation of the beginning and ending balances of the Company's net unrecognized tax benefits is as follows for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 198 $ 220 Additions based on tax positions related to the current year 7 3 Additions for tax positions of prior years 6 46 Reductions for tax positions of prior years (11 ) (58 ) Statute of limitations (1 ) (6 ) Settlements (67 ) (6 ) Interest and penalties (4 ) (1 ) Ending balance $ 128 $ 198
PacifiCorp [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Components of Income Tax Expense (Benefit) [Table Text Block]	Income tax expense (benefit) consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Current: Federal $ 169 $ 130 $ 2 State 32 26 10 Total 201 156 12 Deferred: Federal 123 148 260 State 21 29 43 Total 144 177 303 Investment tax credits (5 ) (5 ) (6 ) Total income tax expense $ 340 $ 328 $ 309
Effective Income Tax Rate Reconciliation [Table Text Block]	A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income before income tax expense is as follows for the years ended December 31: 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % State income taxes, net of federal income tax benefit 3 3 3 Federal income tax credits (6 ) (6 ) (7 ) Other (1 ) — — Effective income tax rate 31 % 32 % 31 %
Components of Net Deferred Income Tax Liability [Table Text Block]	The net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Regulatory liabilities $ 393 $ 374 Employee benefits 202 189 Derivative contracts and unamortized contract values 67 94 State carryforwards 69 68 Loss contingencies 12 67 Asset retirement obligations 78 81 Other 82 88 903 961 Deferred income tax liabilities: Property, plant and equipment (5,161 ) (5,030 ) Regulatory assets (586 ) (639 ) Other (36 ) (42 ) (5,783 ) (5,711 ) Net deferred income tax liability $ (4,880 ) $ (4,750 )
Summary of Operating Loss Carryforwards [Table Text Block]	The following table provides PacifiCorp's net operating loss and tax credit carryforwards and expiration dates as of December 31, 2016 (in millions): State Net operating loss carryforwards $ 1,415 Deferred income taxes on net operating loss carryforwards $ 52 Expiration dates 2017 - 2032 Tax credit carryforwards $ 17 Expiration dates 2017 - indefinite
MidAmerican Energy Company [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Components of Income Tax Expense (Benefit) [Table Text Block]	MidAmerican Energy's income tax benefit from continuing operations consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Current: Federal $ (479 ) $ (415 ) $ (411 ) State (14 ) (6 ) (4 ) (493 ) (421 ) (415 ) Deferred: Federal 366 281 298 State (4 ) (6 ) 2 362 275 300 Investment tax credits (1 ) (1 ) (1 ) Total $ (132 ) $ (147 ) $ (116 )
Effective Income Tax Rate Reconciliation [Table Text Block]	A reconciliation of the federal statutory income tax rate to MidAmerican Energy's effective income tax rate applicable to income before income tax benefit from continuing operations is as follows for the years ended December 31: 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (61 ) (71 ) (65 ) State income tax, net of federal income tax benefit (3 ) (2 ) — Effects of ratemaking (3 ) (12 ) (9 ) Other, net — 1 (2 ) Effective income tax rate (32 )% (49 )% (41 )%
Components of Net Deferred Income Tax Liability [Table Text Block]	MidAmerican Energy's net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Regulatory liabilities $ 333 $ 327 Asset retirement obligations 230 214 Employee benefits 66 66 Other 74 88 Total deferred income tax assets 703 695 Deferred income tax liabilities: Depreciable property (3,763 ) (3,321 ) Regulatory assets (471 ) (418 ) Other (41 ) (17 ) Total deferred income tax liabilities (4,275 ) (3,756 ) Net deferred income tax liability $ (3,572 ) $ (3,061 )
Net Unrecognized Tax Benefits Roll Forward [Table Text Block]	A reconciliation of the beginning and ending balances of MidAmerican Energy's net unrecognized tax benefits is as follows for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 10 $ 26 Additions based on tax positions related to the current year — 3 Additions for tax positions of prior years 10 47 Reductions based on tax positions related to the current year (2 ) (6 ) Reductions for tax positions of prior years (8 ) (46 ) Statute of limitations — (5 ) Settlements — (6 ) Interest and penalties — (3 ) Ending balance $ 10 $ 10
MidAmerican Funding, LLC and Subsidiaries [Domain]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Components of Income Tax Expense (Benefit) [Table Text Block]	MidAmerican Funding's income tax benefit from continuing operations consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Current: Federal $ (485 ) $ (418 ) $ (414 ) State (16 ) (8 ) (5 ) (501 ) (426 ) (419 ) Deferred: Federal 367 282 296 State (4 ) (5 ) 2 363 277 298 Investment tax credits (1 ) (1 ) (1 ) Total $ (139 ) $ (150 ) $ (122 )
Effective Income Tax Rate Reconciliation [Table Text Block]	A reconciliation of the federal statutory income tax rate MidAmerican Funding's the effective income tax rate applicable to income before income tax benefit from continuing operations is as follows for the years ended December 31: 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (64 ) (72 ) (68 ) State income tax, net of federal income tax benefit (3 ) (3 ) (1 ) Effects of ratemaking (3 ) (12 ) (10 ) Other, net — 1 (1 ) Effective income tax rate (35 )% (51 )% (45 )%
Components of Net Deferred Income Tax Liability [Table Text Block]	MidAmerican Funding's net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Regulatory liabilities $ 333 $ 327 Employee benefits 66 66 Asset retirement obligations 230 214 Other 82 97 Total deferred income tax assets 711 704 Deferred income tax liabilities: Depreciable property (3,767 ) (3,326 ) Regulatory assets (471 ) (418 ) Other (41 ) (16 ) Total deferred income tax liabilities (4,279 ) (3,760 ) Net deferred income tax liability $ (3,568 ) $ (3,056 )
Net Unrecognized Tax Benefits Roll Forward [Table Text Block]	A reconciliation of the beginning and ending balances of MidAmerican Funding's net unrecognized tax benefits is as follows for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 10 $ 26 Additions based on tax positions related to the current year — 4 Additions for tax positions of prior years 10 46 Reductions based on tax positions related to the current year (2 ) (6 ) Reductions for tax positions of prior years (8 ) (46 ) Statute of limitations — (5 ) Settlements — (6 ) Interest and penalties — (3 ) Ending balance $ 10 $ 10
Nevada Power Company [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Components of Income Tax Expense (Benefit) [Table Text Block]	Income tax expense (benefit) consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Current – Federal $ 68 $ — $ — Deferred – Federal 79 163 131 Investment tax credits (1 ) (1 ) (1 ) Total income tax expense $ 146 $ 162 $ 130
Effective Income Tax Rate Reconciliation [Table Text Block]	A reconciliation of the federal statutory income rate to the effective income tax rate applicable to income before income tax expense is as follows for the years ended December 31 : 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % Effects of ratemaking — 1 1 Other (1 ) — — Effective income tax rate 34 % 36 % 36 %
Components of Net Deferred Income Tax Liability [Table Text Block]	The net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Capital and financial leases 170 174 Regulatory liabilities 83 47 Employee benefits 29 30 Customer advances 23 22 Federal net operating loss and credit carryforwards 5 15 Other 16 17 Total deferred income tax assets 326 305 Valuation allowance (5 ) (5 ) Total deferred income tax assets, net 321 300 Deferred income tax liabilities: Property related items (1,293 ) (1,242 ) Regulatory assets (321 ) (275 ) Capital and financial leases (165 ) (169 ) Other (16 ) (19 ) Total deferred income tax liabilities (1,795 ) (1,705 ) Net deferred income tax liability $ (1,474 ) $ (1,405 )
Summary of Operating Loss Carryforwards [Table Text Block]	The following table provides Nevada Power 's tax credit carryforwards and expiration dates as of December 31 , 2016 (in millions): Other tax credits $ 5 Expiration dates 2017 - 2028
Sierra Pacific Power Company [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Components of Income Tax Expense (Benefit) [Table Text Block]	Income tax expense (benefit) consists of the following for the years ended December 31 (in millions): 2016 2015 2014 Deferred - Federal $ 50 $ 48 $ 48 Investment tax credits (1 ) (1 ) (1 ) Total income tax expense $ 49 $ 47 $ 47
Effective Income Tax Rate Reconciliation [Table Text Block]	A reconciliation of the federal statutory income rate to the effective income tax rate applicable to income before income tax expense is as follows for the years ended December 31 : 2016 2015 2014 Federal statutory income tax rate 35 % 35 % 35 % Effects of ratemaking 1 1 1 Other 1 — (1 ) Effective income tax rate 37 % 36 % 35 %
Components of Net Deferred Income Tax Liability [Table Text Block]	The net deferred income tax liability consists of the following as of December 31 (in millions): 2016 2015 Deferred income tax assets: Federal net operating loss and credit carryforwards $ 25 $ 39 Employee benefit plans 22 25 Regulatory liabilities 16 19 Capital and financial lease liabilities 12 13 Customer Advances 9 8 Commodity derivative contract 5 5 Other 6 7 Total deferred income tax assets $ 95 $ 116 Deferred income tax liabilities: Property related items $ (562 ) $ (538 ) Regulatory assets (124 ) (121 ) Capital and financial leases (12 ) (13 ) Other (14 ) (14 ) Total deferred income tax liabilities $ (712 ) $ (686 ) Net deferred income tax liability $ (617 ) $ (570 )
Summary of Operating Loss Carryforwards [Table Text Block]	The following table provides Sierra Pacific 's federal net operating loss and tax credit carryforwards and expiration dates as of December 31 , 2016 (in millions): Net operating loss carryforwards $ 55 Deferred income taxes on federal net operating loss carryforwards $ 19 Expiration dates 2031 - 2033 Other tax credits $ 6 Expiration dates 2021 - 2032

Supplemental Cash Flow Disclo56

Supplemental Cash Flow Disclosures (Tables)	12 Months Ended
	Dec. 31, 2016
Condensed Cash Flow Statements, Captions [Line Items]
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	The summary of supplemental cash flow disclosures as of and for the years ending December 31 is as follows (in millions): 2016 2015 2014 Supplemental disclosure of cash flow information: Interest paid, net of amounts capitalized $ 1,673 $ 1,764 $ 1,585 Income taxes received, net (1) $ 1,016 $ 1,666 $ 635 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 547 $ 718 $ 1,143 (1) Includes $1.1 billion , $1.8 billion and $764 million of income taxes received from Berkshire Hathaway in 2016 , 2015 and 2014 , respectively.
PacifiCorp [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	The summary of supplemental cash flow disclosures as of and for the years ended December 31 is as follows (in millions): 2016 2015 2014 Interest paid, net of amounts capitalized $ 350 $ 342 $ 340 Income taxes paid, net $ 201 $ 40 $ 161 Supplemental disclosure of non-cash investing and financing activities: Accounts payable related to property, plant and equipment additions $ 101 $ 147 $ 140 Accounts receivable related to property, plant and equipment sales $ — $ 40 $ —
MidAmerican Energy Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	The summary of supplemental cash flow disclosures as of and for the years ending December 31 is as follows (in millions): 2016 2015 2014 Supplemental cash flow information: Interest paid, net of amounts capitalized $ 181 $ 154 $ 144 Income taxes received, net $ 601 $ 629 $ 149 Supplemental disclosure of non-cash investing transactions: Accounts payable related to utility plant additions $ 131 $ 249 $ 128 Dividend of unregulated retail services business (Note 3) $ 90 $ — $ —
MidAmerican Funding, LLC and Subsidiaries [Domain]
Condensed Cash Flow Statements, Captions [Line Items]
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	The summary of supplemental cash flow information as of and for the years ending December 31 is as follows (in millions): 2016 2015 2014 Supplemental cash flow information: Interest paid, net of amounts capitalized $ 204 $ 177 $ 167 Income taxes received, net $ 609 $ 630 $ 153 Supplemental disclosure of non-cash investing transactions: Accounts payable related to utility plant additions $ 131 $ 249 $ 128 Transfer of assets and liabilities to affiliate (Note 3) $ 90 $ — $ —
Nevada Power Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	The summary of supplemental cash flow disclosures as of and for the years ended December 31 is as follows (in millions): 2016 2015 2014 Supplemental disclosure of cash flow information - Interest paid, net of amounts capitalized $ 173 $ 186 $ 194 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 19 $ 51 $ 30 Capital and financial lease obligations incurred $ (1 ) $ (5 ) $ 7
Sierra Pacific Power Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	The summary of supplemental cash flow disclosures as of and for the years ended December 31 is as follows (in millions): 2016 2015 2014 Supplemental disclosure of cash flow information - Interest paid, net of amounts capitalized $ 47 $ 54 $ 54 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 15 $ 24 $ 31 Capital and financial lease obligations incurred $ — $ 13 $ 1

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following table presents the Company's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Other (1) Total As of December 31, 2016: Assets: Commodity derivatives $ 5 $ 49 $ 87 $ (22 ) $ 119 Interest rate derivatives — 16 7 — 23 Mortgage loans held for sale — 359 — — 359 Money market mutual funds (2) 586 — — — 586 Debt securities: United States government obligations 161 — — — 161 International government obligations — 3 — — 3 Corporate obligations — 36 — — 36 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Equity securities: United States companies 250 — — — 250 International companies 1,190 — — — 1,190 Investment funds 147 — — — 147 $ 2,339 $ 467 $ 94 $ (22 ) $ 2,878 Liabilities: Commodity derivatives $ (2 ) $ (199 ) $ (27 ) $ 96 $ (132 ) Interest rate derivatives (1 ) (11 ) (1 ) — (13 ) $ (3 ) $ (210 ) $ (28 ) $ 96 $ (145 ) As of December 31, 2015: Assets: Commodity derivatives $ — $ 16 $ 93 $ (16 ) $ 93 Interest rate derivatives — 5 5 — 10 Mortgage loans held for sale — 327 — — 327 Money market mutual funds (2) 421 — — — 421 Debt securities: United States government obligations 133 — — — 133 International government obligations — 2 — — 2 Corporate obligations — 39 — — 39 Municipal obligations — 1 — — 1 Agency, asset and mortgage-backed obligations — 3 — — 3 Auction rate securities — — 44 — 44 Equity securities: United States companies 239 — — — 239 International companies 1,244 — — — 1,244 Investment funds 136 — — — 136 $ 2,173 $ 393 $ 142 $ (16 ) $ 2,692 Liabilities: Commodity derivatives $ (13 ) $ (283 ) $ (46 ) $ 119 $ (223 ) Interest rate derivatives — (13 ) (1 ) — (14 ) $ (13 ) $ (296 ) $ (47 ) $ 119 $ (237 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $74 million and $103 million as of December 31, 2016 and 2015 , respectively. (2) Amounts are included in cash and cash equivalents; other current assets; and noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Net Benefit Costs [Table Text Block]	Net periodic benefit cost for the plans included the following components for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Service cost $ 29 $ 33 $ 36 $ 9 $ 11 $ 14 Interest cost 126 121 131 31 31 46 Expected return on plan assets (160 ) (169 ) (164 ) (41 ) (45 ) (53 ) Net amortization 46 53 44 (12 ) (11 ) (3 ) Net periodic benefit cost (credit) $ 41 $ 38 $ 47 $ (13 ) $ (14 ) $ 4
Changes in Fair Value of Plan Assets [Table Text Block]	The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, beginning of year $ 2,489 $ 2,718 $ 662 $ 858 Employer contributions 78 13 2 2 Participant contributions — — 10 9 Actual return on plan assets 163 (17 ) 41 — Settlement (11 ) (23 ) — (150 ) Benefits paid (194 ) (202 ) (49 ) (57 ) Plan assets at fair value, end of year $ 2,525 $ 2,489 $ 666 $ 662
Changes in Projected Benefit Obligations [Table Text Block]	The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Benefit obligation, beginning of year $ 2,934 $ 3,119 $ 740 $ 936 Service cost 29 33 9 11 Interest cost 126 121 31 31 Participant contributions — — 10 9 Actuarial loss (gain) 67 (110 ) (7 ) (43 ) Amendment 1 (4 ) — 3 Settlement (11 ) (23 ) — (150 ) Benefits paid (194 ) (202 ) (49 ) (57 ) Benefit obligation, end of year $ 2,952 $ 2,934 $ 734 $ 740 Accumulated benefit obligation, end of year $ 2,929 $ 2,906
Benefit Obligations in Excess of Fair Value of Plan Assets [Table Text Block]	The fair value of plan assets, projected benefit obligation and accumulated benefit obligation for (1) pension and other postretirement benefit plans with a projected benefit obligation in excess of the fair value of plan assets and (2) pension plans with an accumulated benefit obligation in excess of the fair value of plan assets as of December 31 are as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Fair value of plan assets $ 1,841 $ 1,811 $ 413 $ 413 Projected benefit obligation $ 2,294 $ 2,263 $ 500 $ 505 Accumulated benefit obligation $ 2,278 $ 2,244 The funded status of the plans and the amounts recognized on the Consolidated Balance Sheets as of December 31 are as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, end of year $ 2,525 $ 2,489 $ 666 $ 662 Benefit obligation, end of year 2,952 2,934 734 740 Funded status $ (427 ) $ (445 ) $ (68 ) $ (78 ) Amounts recognized on the Consolidated Balance Sheets: Other assets $ 26 $ 7 $ 19 $ 15 Other current liabilities (15 ) (15 ) — — Other long-term liabilities (438 ) (437 ) (87 ) (93 ) Amounts recognized $ (427 ) $ (445 ) $ (68 ) $ (78 )
Net Periodic Benefit Costs Not Yet Recognized [Table Text Block]	A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2016 and 2015 is as follows (in millions): Accumulated Other Regulatory Regulatory Comprehensive Asset Liability Loss Total Pension Balance, December 31, 2014 $ 710 $ (6 ) $ 19 $ 723 Net loss (gain) arising during the year 76 5 (6 ) 75 Net prior service credit arising during the year (4 ) — — (4 ) Net amortization (53 ) — — (53 ) Total 19 5 (6 ) 18 Balance, December 31, 2015 729 (1 ) 13 741 Net loss arising during the year 76 (11 ) — 65 Net prior service cost arising during the year 1 — — 1 Net amortization (45 ) (1 ) — (46 ) Total 32 (12 ) — 20 Balance, December 31, 2016 $ 761 $ (13 ) $ 13 $ 761 Regulatory Regulatory Asset Liability Total Other Postretirement Balance, December 31, 2014 $ 37 $ (14 ) $ 23 Net (gain) loss arising during the year (1 ) 1 — Net prior service cost arising during the year 3 — 3 Net amortization 10 1 11 Total 12 2 14 Balance, December 31, 2015 49 (12 ) 37 Net gain arising during the year (5 ) (1 ) (6 ) Net amortization 11 1 12 Total 6 — 6 Balance, December 31, 2016 $ 55 $ (12 ) $ 43 The portion of the funded status of the plans not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Net loss $ 775 $ 768 $ 88 $ 97 Prior service credit (7 ) (25 ) (52 ) (68 ) Regulatory deferrals (7 ) (2 ) 7 8 Total $ 761 $ 741 $ 43 $ 37
Defined Benefit Plans, Amounts To Be Recognized In Following Year [Table Text Block]	The net loss, prior service credit and regulatory deferrals that will be amortized in 2017 into net periodic benefit cost are estimated to be as follows (in millions): Net Prior Service Regulatory Loss Credit Deferrals Total Pension $ 33 $ (3 ) $ (2 ) $ 28 Other postretirement 2 (16 ) 1 (13 ) Total $ 35 $ (19 ) $ (1 ) $ 15
Plan Assumptions [Table Text Block]	Weighted-average assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Benefit obligations as of December 31: Discount rate 4.06 % 4.43 % 4.00 % 4.01 % 4.33 % 3.88 % Rate of compensation increase 2.75 % 2.75 % 2.75 % N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.43 % 4.00 % 4.81 % 4.33 % 3.93 % 4.82 % Expected return on plan assets 6.78 % 6.88 % 6.86 % 7.03 % 7.00 % 7.34 % Rate of compensation increase 2.75 % 2.75 % 3.00 % N/A N/A N/A In establishing its assumption as to the expected return on plan assets, the Company utilizes the asset allocation and return assumptions for each asset class based on historical performance and forward-looking views of the financial markets. 2016 2015 Assumed healthcare cost trend rates as of December 31: Healthcare cost trend rate assumed for next year 7.40 % 7.70 % Rate that the cost trend rate gradually declines to 5.00 % 5.00 % Year that the rate reaches the rate it is assumed to remain at 2025 2025
Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates [Table Text Block]	A one percentage-point change in assumed healthcare cost trend rates would have the following effects (in millions): One Percentage-Point Increase Decrease Increase (decrease) in: Total service and interest cost for the year ended December 31, 2016 $ 1 $ — Other postretirement benefit obligation as of December 31, 2016 4 (4 )
Expected Benefit Payments [Table Text Block]	The expected benefit payments to participants in the Company's pension and other postretirement benefit plans for 2017 through 2021 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Other Pension Postretirement 2017 $ 219 $ 56 2018 226 57 2019 224 57 2020 221 60 2021 214 57 2022-2026 1,002 259
Allocation of Plan Assets [Table Text Block]	The target allocations (percentage of plan assets) for the Company's pension and other postretirement benefit plan assets are as follows as of December 31, 2016 : Other Pension Postretirement % % PacifiCorp: Debt securities (1) 33-37 33-37 Equity securities (1) 53-57 61-65 Limited partnership interests 8-12 1-3 Other 0-1 0-1 MidAmerican Energy: Debt securities (1) 20-40 25-45 Equity securities (1) 60-80 50-80 Real estate funds 2-8 — Other 0-5 0-5 NV Energy: Debt securities (1) 53-77 40 Equity securities (1) 23-47 60 (1) For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.
Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following table presents the fair value of plan assets, by major category, for the Company's defined benefit pension plans (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 4 $ 54 $ — $ 58 Debt securities: United States government obligations 161 — — 161 International government obligations — 2 — 2 Corporate obligations — 295 — 295 Municipal obligations — 20 — 20 Agency, asset and mortgage-backed obligations — 112 — 112 Equity securities: United States companies 583 — — 583 International companies 117 — — 117 Investment funds (2) 146 — — 146 Total assets in the fair value hierarchy $ 1,011 $ 483 $ — 1,494 Investment funds (2) measured at net asset value 920 Limited partnership interests (3) measured at net asset value 61 Real estate funds measured at net asset value 50 Total assets measured at fair value $ 2,525 As of December 31, 2015: Cash equivalents $ — $ 26 $ — $ 26 Debt securities: United States government obligations 155 — — 155 International government obligations — 4 — 4 Corporate obligations — 335 — 335 Municipal obligations — 25 — 25 Agency, asset and mortgage-backed obligations — 154 — 154 Equity securities: United States companies 586 — — 586 International companies 122 — — 122 Investment funds (2) 144 — — 144 Total assets in the fair value hierarchy $ 1,007 $ 544 $ — 1,551 Investment funds (2) measured at net asset value 823 Limited partnership interests (3) measured at net asset value 65 Real estate funds measured at net asset value 50 Total assets measured at fair value $ 2,489 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 62% and 38% , respectively, for 2016 and 66% and 34% , respectively, for 2015 . Additionally, these funds are invested in United States and international securities of approximately 60% and 40% , respectively, for 2016 and 58% and 42% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. The following table presents the fair value of plan assets, by major category, for the Company's defined benefit other postretirement plans (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 18 $ 2 $ — $ 20 Debt securities: United States government obligations 19 — — 19 Corporate obligations — 29 — 29 Municipal obligations — 39 — 39 Agency, asset and mortgage-backed obligations — 25 — 25 Equity securities: United States companies 217 — — 217 International companies 5 — — 5 Investment funds (2) 152 — — 152 Total assets in the fair value hierarchy $ 411 $ 95 $ — 506 Investment funds (2) measured at net asset value 156 Limited partnership interests (3) measured at net asset value 4 Total assets measured at fair value $ 666 As of December 31, 2015: Cash equivalents $ 12 $ 1 $ — $ 13 Debt securities: United States government obligations 18 — — 18 Corporate obligations — 33 — 33 Municipal obligations — 41 — 41 Agency, asset and mortgage-backed obligations — 28 — 28 Equity securities: United States companies 216 — — 216 International companies 6 — — 6 Investment funds (2) 149 — — 149 Total assets in the fair value hierarchy $ 401 $ 103 $ — 504 Investment funds (2) measured at net asset value 154 Limited partnership interests (3) measured at net asset value 4 Total assets measured at fair value $ 662 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 63% and 37% , respectively, for both 2016 and 2015 . Additionally, these funds are invested in United States and international securities of approximately 72% and 28% , respectively, for 2016 and 70% and 30% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Net Benefit Costs [Table Text Block]	Net periodic benefit cost for the UK Plan included the following components for the years ended December 31 (in millions): 2016 2015 2014 Service cost $ 20 $ 24 $ 24 Interest cost 72 79 95 Expected return on plan assets (110 ) (116 ) (124 ) Net amortization 44 62 51 Net periodic benefit cost $ 26 $ 49 $ 46
Changes in Fair Value of Plan Assets [Table Text Block]	The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): 2016 2015 Plan assets at fair value, beginning of year $ 2,276 $ 2,368 Employer contributions 55 77 Participant contributions 1 2 Actual return on plan assets 349 48 Benefits paid (115 ) (91 ) Foreign currency exchange rate changes (397 ) (128 ) Plan assets at fair value, end of year $ 2,169 $ 2,276
Changes in Projected Benefit Obligations [Table Text Block]	following table is a reconciliation of the benefit obligation for the years ended December 31 (in millions): 2016 2015 Benefit obligation, beginning of year $ 2,142 $ 2,279 Service cost 20 24 Interest cost 72 79 Participant contributions 1 2 Actuarial loss (gain) 387 (30 ) Benefits paid (115 ) (91 ) Foreign currency exchange rate changes (382 ) (121 ) Benefit obligation, end of year $ 2,125 $ 2,142 Accumulated benefit obligation, end of year $ 1,858 $ 1,891
Benefit Obligations in Excess of Fair Value of Plan Assets [Table Text Block]	The funded status of the UK Plan and the amounts recognized on the Consolidated Balance Sheets as of December 31 are as follows (in millions): 2016 2015 Plan assets at fair value, end of year $ 2,169 $ 2,276 Benefit obligation, end of year 2,125 2,142 Funded status $ 44 $ 134 Amounts recognized on the Consolidated Balance Sheets: Other assets $ 44 $ 134
Net Periodic Benefit Costs Not Yet Recognized [Table Text Block]	A reconciliation of the amounts not yet recognized as components of net periodic benefit cost, which are included in accumulated other comprehensive loss on the Consolidated Balance Sheets, for the years ended December 31 is as follows (in millions): 2016 2015 Balance, beginning of year $ 592 $ 655 Net loss arising during the year 148 38 Net amortization (44 ) (62 ) Foreign currency exchange rate changes (106 ) (39 ) Total (2 ) (63 ) Balance, end of year $ 590 $ 592 The portion of the funded status of the UK Plan not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions): 2016 2015 Net loss $ 590 $ 592
Plan Assumptions [Table Text Block]	Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: 2016 2015 2014 Benefit obligations as of December 31: Discount rate 2.70 % 3.70 % 3.60 % Rate of compensation increase 3.00 % 2.90 % 2.80 % Rate of future price inflation 3.00 % 2.90 % 2.80 % Net periodic benefit cost for the years ended December 31: Discount rate 3.70 % 3.60 % 4.40 % Expected return on plan assets 5.60 % 5.60 % 6.10 % Rate of compensation increase 2.90 % 2.80 % 3.15 % Rate of future price inflation 2.90 % 2.80 % 3.15 %
Expected Benefit Payments [Table Text Block]	Employer contributions to the UK Plan are expected to be £37 million during 2017 . The expected benefit payments to participants in the UK Plan for 2017 through 2021 and for the five years thereafter, using the foreign currency exchange rate as of December 31, 2016 , are summarized below (in millions): 2017 $ 75 2018 77 2019 79 2020 81 2021 83 2022-2026 448
Allocation of Plan Assets [Table Text Block]	The target allocations (percentage of plan assets) for the UK Plan assets are as follows as of December 31, 2016 : % Debt securities (1) 50-55 Equity securities (1) 35-40 Real estate funds and other 5-15 (1) For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds have been allocated based on the underlying investments in debt and equity securities.
Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The Company adopted ASU No. 2015-07, "Fair Value Measurement (Topic 820) - Disclosures for Investments in Certain Entities that Calculate Net Asset Value per Share (or its Equivalent)" effective January 1, 2016 under a retrospective method. The following table presents the fair value of the UK Plan assets, by major category, (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 4 $ 83 $ — $ 87 Debt securities: United Kingdom government obligations 718 — — 718 Equity securities: Investment funds (2) — 1,095 — 1,095 Real estate funds — — 105 105 Total $ 722 $ 1,178 $ 105 2,005 Investment funds (2) measured at net asset value 164 Total assets measured at fair value $ 2,169 As of December 31, 2015: Cash equivalents $ 46 $ — $ — $ 46 Debt securities: United Kingdom government obligations 424 — — 424 Other international government obligations — 13 — 13 Corporate obligations — 186 — 186 Equity securities: Investment funds (2) 24 1,189 — 1,213 Real estate funds — — 204 204 Total $ 494 $ 1,388 $ 204 2,086 Investment funds (2) measured at net asset value 190 Total assets measured at fair value $ 2,276 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 44% and 56% , respectively, for both 2016 and 2015 .
Level Three Defined Benefit Plan Assets Roll Forward [Table Text Block]	The following table reconciles the beginning and ending balances of the UK Plan assets measured at fair value using significant Level 3 inputs for the years ended December 31 (in millions): Real Estate Funds 2016 2015 2014 Beginning balance $ 204 $ 199 $ 179 Actual return on plan assets still held at period end 10 18 33 Sales (80 ) — — Foreign currency exchange rate changes (29 ) (13 ) (13 ) Ending balance $ 105 $ 204 $ 199
PacifiCorp [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Net Benefit Costs [Table Text Block]	Net periodic benefit cost for the plans included the following components for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Service cost $ 4 $ 4 $ 5 $ 2 $ 3 $ 6 Interest cost 54 53 57 15 16 28 Expected return on plan assets (75 ) (77 ) (76 ) (21 ) (23 ) (31 ) Net amortization 34 42 29 (5 ) (4 ) 2 Net periodic benefit cost (credit) $ 17 $ 22 $ 15 $ (9 ) $ (8 ) $ 5
Changes in Fair Value of Plan Assets [Table Text Block]	The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, beginning of year $ 1,043 $ 1,146 $ 305 $ 482 Employer contributions 5 4 1 1 Participant contributions — — 6 6 Actual return on plan assets 51 — 17 1 Settlement — — — (150 ) Benefits paid (100 ) (107 ) (27 ) (35 ) Plan assets at fair value, end of year $ 999 $ 1,043 $ 302 $ 305
Changes in Projected Benefit Obligations [Table Text Block]	The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Benefit obligation, beginning of year $ 1,289 $ 1,378 $ 362 $ 539 Service cost 4 4 2 3 Interest cost 54 53 15 16 Participant contributions — — 6 6 Actuarial (gain) loss 29 (39 ) — (17 ) Settlement — — — (150 ) Benefits paid (100 ) (107 ) (27 ) (35 ) Benefit obligation, end of year $ 1,276 $ 1,289 $ 358 $ 362 Accumulated benefit obligation, end of year $ 1,276 $ 1,289
Benefit Obligations in Excess of Fair Value of Plan Assets [Table Text Block]	The funded status of the plans and the amounts recognized on the Consolidated Balance Sheets as of December 31 are as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, end of year $ 999 $ 1,043 $ 302 $ 305 Less - Benefit obligation, end of year 1,276 1,289 358 362 Funded status $ (277 ) $ (246 ) $ (56 ) $ (57 ) Amounts recognized on the Consolidated Balance Sheets: Other current liabilities $ (5 ) $ (4 ) $ — $ — Other long-term liabilities (272 ) (242 ) (56 ) (57 ) Amounts recognized $ (277 ) $ (246 ) $ (56 ) $ (57 )
Net Periodic Benefit Costs Not Yet Recognized [Table Text Block]	The portion of the funded status of the plans not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Net loss $ 518 $ 508 $ 39 $ 36 Prior service credit — (13 ) (13 ) (19 ) Regulatory deferrals (7 ) (3 ) 8 9 Total $ 511 $ 492 $ 34 $ 26 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2016 and 2015 is as follows (in millions): Accumulated Other Regulatory Comprehensive Asset Loss Total Pension Balance, December 31, 2014 $ 474 $ 22 $ 496 Net loss (gain) arising during the year 40 (2 ) 38 Net amortization (41 ) (1 ) (42 ) Total (1 ) (3 ) (4 ) Balance, December 31, 2015 473 19 492 Net loss arising during the year 51 2 53 Net amortization (33 ) (1 ) (34 ) Total 18 1 19 Balance, December 31, 2016 $ 491 $ 20 $ 511 Regulatory Asset Other Postretirement Balance, December 31, 2014 $ 17 Net loss arising during the year 5 Net amortization 4 Total 9 Balance, December 31, 2015 26 Net loss arising during the year 3 Net amortization 5 Total 8 Balance, December 31, 2016 $ 34
Defined Benefit Plans, Amounts To Be Recognized In Following Year [Table Text Block]	The net loss, prior service credit and regulatory deferrals that will be amortized in 2017 into net periodic benefit cost are estimated to be as follows (in millions): Net Prior Service Regulatory Loss Credit Deferrals Total Pension $ 16 $ — $ (2 ) $ 14 Other postretirement — (7 ) 1 (6 ) Total $ 16 $ (7 ) $ (1 ) $ 8
Plan Assumptions [Table Text Block]	Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Benefit obligations as of December 31: Discount rate 4.05 % 4.40 % 4.00 % 4.05 % 4.35 % 3.90 % Rate of compensation increase N/A 2.75 2.75 N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.40 % 4.00 % 4.80 % 4.35 % 3.99 % 4.90 % Expected return on plan assets 7.50 7.50 7.50 7.50 7.08 7.50 Rate of compensation increase 2.75 2.75 3.00 N/A N/A N/A In establishing its assumption as to the expected return on plan assets, PacifiCorp utilizes the asset allocation and return assumptions for each asset class based on historical performance and forward-looking views of the financial markets. As discussed above in "Utah Mine Disposition and Labor Agreement," PacifiCorp remeasured the other postretirement plan assets and benefit obligation as of May 31, 2015. The other postretirement assumptions for the year ended December 31, 2015 presented above reflect a weighted average calculation that considered the assumptions used in the periods preceding and subsequent to the remeasurement. As a result of a plan amendment effective on January 1, 2017, the benefit obligation for the Retirement Plan is no longer affected by future increases in compensation. As a result of the labor settlement discussed above in "Utah Mine Disposition and Labor Agreement," the benefit obligation for the other postretirement plan is no longer affected by healthcare cost trends.
Expected Benefit Payments [Table Text Block]	The expected benefit payments to participants in PacifiCorp's pension and other postretirement benefit plans for 2017 through 2021 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Pension Other Postretirement 2017 $ 105 $ 28 2018 109 28 2019 108 27 2020 104 30 2021 97 26 2022-2026 426 116
Allocation of Plan Assets [Table Text Block]	The target allocations (percentage of plan assets) for PacifiCorp's pension and other postretirement benefit plan assets are as follows as of December 31, 2016 : Pension (1) Other Postretirement (1) % % Debt securities (2) 33 - 37 33 - 37 Equity securities (2) 53 - 57 61 - 65 Limited partnership interests 8 - 12 1 - 3 Other 0 - 1 0 - 1 (1) PacifiCorp's Retirement Plan trust includes a separate account that is used to fund benefits for the other postretirement benefit plan. In addition to this separate account, the assets for the other postretirement benefit plan are held in Voluntary Employees' Beneficiary Association ("VEBA") trusts, each of which has its own investment allocation strategies. Target allocations for the other postretirement benefit plan include the separate account of the Retirement Plan trust and the VEBA trusts. (2) For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.
Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following table presents the fair value of plan assets, by major category, for PacifiCorp's defined benefit pension plan (in millions): Input Levels for Fair Value Measurements Level 1 (1) Level 2 (1) Level 3 (1) Total As of December 31, 2016: Cash equivalents $ — $ 10 $ — $ 10 Debt securities: United States government obligations 25 — — 25 Corporate obligations — 36 — 36 Municipal obligations — 6 — 6 Agency, asset and mortgage-backed obligations — 37 — 37 Equity securities: United States companies 389 — — 389 International companies 15 — — 15 Investment funds (2) 83 — — 83 Total assets in the fair value hierarchy $ 512 $ 89 $ — 601 Investment funds (2) measured at net asset value 337 Limited partnership interests (3) measured at net asset value 61 Investments at fair value $ 999 As of December 31, 2015: Cash equivalents $ — $ 10 $ — $ 10 Debt securities: United States government obligations 19 — — 19 Corporate obligations — 42 — 42 Municipal obligations — 5 — 5 Agency, asset and mortgage-backed obligations — 43 — 43 Equity securities: United States companies 408 — — 408 International companies 17 — — 17 Investment funds (2) 83 — — 83 Total assets in the fair value hierarchy $ 527 $ 100 $ — 627 Investment funds (2) measured at net asset value 351 Limited partnership interests (3) measured at net asset value 65 Investments at fair value $ 1,043 (1) Refer to Note 12 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are substantially comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 54% and 46% respectively, for 2016 and 53% and 47% , respectively, for 2015 , and are invested in United States and international securities of approximately 39% and 61% , respectively, for 2016 and 40% and 60% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. The following table presents the fair value of plan assets, by major category, for PacifiCorp's defined benefit other postretirement plan (in millions): Input Levels for Fair Value Measurements Level 1 (1) Level 2 (1) Level 3 (1) Total As of December 31, 2016: Cash and cash equivalents $ 4 $ 1 $ — $ 5 Debt securities: United States government obligations 11 — — 11 Corporate obligations — 13 — 13 Municipal obligations — 2 — 2 Agency, asset and mortgage-backed obligations — 13 — 13 Equity securities: United States companies 93 — — 93 International companies 4 — — 4 Investment funds (2) 32 — — 32 Total assets in the fair value hierarchy $ 144 $ 29 $ — 173 Investment funds (2) measured at net asset value 125 Limited partnership interests (3) measured at net asset value 4 Investments at fair value $ 302 As of December 31, 2015: Cash and cash equivalents $ 4 $ 1 $ — $ 5 Debt securities: United States government obligations 9 — — 9 Corporate obligations — 15 — 15 Municipal obligations — 1 — 1 Agency, asset and mortgage-backed obligations — 14 — 14 Equity securities: United States companies 95 — — 95 International companies 4 — — 4 Investment funds (2) 32 — — 32 Total assets in the fair value hierarchy $ 144 $ 31 $ — 175 Investment funds (2) measured at net asset value 126 Limited partnership interests (3) measured at net asset value 4 Investments at fair value $ 305 (1) Refer to Note 12 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are substantially comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 62% and 38% , respectively, for 2016 and 61% and 39% , respectively, for 2015 , and are invested in United States and international securities of approximately 71% and 29% , respectively, for 2016 and 67% and 33% , respectively, for 2015 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. The following table presents PacifiCorp's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Other (1) Total As of December 31, 2016: Assets: Commodity derivatives $ — $ 27 $ — $ (7 ) $ 20 Money market mutual funds (2) 13 — — — 13 Investment funds 17 — — — 17 $ 30 $ 27 $ — $ (7 ) $ 50 Liabilities - Commodity derivatives $ — $ (104 ) $ — $ 76 $ (28 ) As of December 31, 2015: Assets: Commodity derivatives $ — $ 9 $ 3 $ (3 ) $ 9 Money market mutual funds (2) 13 — — — 13 Investment funds 15 — — — 15 $ 28 $ 9 $ 3 $ (3 ) $ 37 Liabilities - Commodity derivatives $ — $ (148 ) $ — $ 78 $ (70 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $69 million and $75 million as of December 31, 2016 and 2015 , respectively. (2) Amounts are included in cash and cash equivalents, other current assets and other assets on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
Schedule of Multiemployer Plans [Table Text Block]	The following table presents PacifiCorp's and Energy West Mining Company's participation in individually significant joint trustee and multiemployer pension plans for the years ended December 31 (dollars in millions): PPA zone status or plan funded status percentage for plan years beginning July 1, Contributions (1) Plan name Employer Identification Number 2016 2015 2014 Funding improvement plan Surcharge imposed under PPA (1) 2016 2015 2014 Year contributions to plan exceeded more than 5% of total contributions (2) UMWA 1974 Pension Plan 52-1050282 Critical and Declining Critical and Declining Critical Implemented Yes $ — $ 1 $ 2 None Local 57 Trust Fund 87-0640888 At least 80% At least 80% At least 80% None None $ 8 $ 8 $ 9 2015, 2014, 2013 (1) PacifiCorp's and Energy West Mining Company's minimum contributions to the plans are based on the amount of wages paid to employees covered by the Local 57 Trust Fund collective bargaining agreements and the number of mining hours worked for the UMWA 1974 Pension Plan, respectively, subject to ERISA minimum funding requirements. As a result of the plan's critical status, Energy West Mining Company was required to begin paying a surcharge for hours worked on and after December 1, 2014. (2) For the UMWA 1974 Pension Plan, information is for plan years beginning July 1, 2014, 2013 and 2012. Information for the plan year beginning July 1, 2015 is not yet available. For the Local 57 Trust Fund, information is for plan years beginning July 1, 2014, 2013 and 2012. Information for the plan year beginning July 1, 2015 is not yet available.
MidAmerican Energy Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Net Benefit Costs [Table Text Block]	Net periodic benefit cost for the plans of MidAmerican Energy and the aforementioned affiliates included the following components for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Service cost $ 10 $ 12 $ 14 $ 5 $ 7 $ 6 Interest cost 34 32 35 10 9 10 Expected return on plan assets (44 ) (46 ) (45 ) (13 ) (15 ) (15 ) Net amortization 2 2 1 (4 ) (3 ) (3 ) Net periodic benefit cost (credit) $ 2 $ — $ 5 $ (2 ) $ (2 ) $ (2 )
Changes in Fair Value of Plan Assets [Table Text Block]	The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, beginning of year $ 678 $ 730 $ 249 $ 259 Employer contributions 7 7 1 1 Participant contributions — — 1 1 Actual return on plan assets 57 4 14 — Benefits paid (58 ) (63 ) (13 ) (12 ) Plan assets at fair value, end of year $ 684 $ 678 $ 252 $ 249
Changes in Projected Benefit Obligations [Table Text Block]	The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2016 2015 Benefit obligation, beginning of year $ 785 $ 840 $ 234 $ 249 Service cost 10 12 5 7 Interest cost 34 32 10 9 Participant contributions — — 1 1 Actuarial loss (gain) 2 (36 ) (4 ) (20 ) Benefits paid (58 ) (63 ) (13 ) (12 ) Benefit obligation, end of year $ 773 $ 785 $ 233 $ 234 Accumulated benefit obligation, end of year $ 764 $ 773
Benefit Obligations in Excess of Fair Value of Plan Assets [Table Text Block]	The funded status of the plans and the amounts recognized on the Balance Sheets as of December 31 are as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Plan assets at fair value, end of year $ 684 $ 678 $ 252 $ 249 Less - Benefit obligation, end of year 773 785 233 234 Funded status $ (89 ) $ (107 ) $ 19 $ 15 Amounts recognized on the Balance Sheets: Other assets $ 26 $ 7 $ 19 $ 15 Other current liabilities (8 ) (8 ) — — Other liabilities (107 ) (106 ) — — Amounts recognized $ (89 ) $ (107 ) $ 19 $ 15
Net Periodic Benefit Costs Not Yet Recognized [Table Text Block]	A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2016 and 2015 is as follows (in millions): Regulatory Asset Regulatory Liability Receivables (Payables) with Affiliates Total Pension Balance, December 31, 2014 $ 22 $ (5 ) $ 7 $ 24 Net loss (gain) arising during the year 2 5 (1 ) 6 Net amortization (2 ) — — (2 ) Total — 5 (1 ) 4 Balance, December 31, 2015 22 — 6 28 Net gain arising during the year 1 (11 ) — (10 ) Net amortization (1 ) (1 ) — (2 ) Total — (12 ) — (12 ) Balance, December 31, 2016 $ 22 $ (12 ) $ 6 $ 16 Regulatory Asset Regulatory Liability Receivables (Payables) with Affiliates Total Other Postretirement Balance, December 31, 2014 $ 20 $ — $ (13 ) $ 7 Net gain arising during the year (5 ) — — (5 ) Net amortization 2 — 2 4 Total (3 ) — 2 (1 ) Balance, December 31, 2015 17 — (11 ) 6 Net gain arising during the year (2 ) — (3 ) (5 ) Net amortization 3 — 1 4 Total 1 — (2 ) (1 ) Balance, December 31, 2016 $ 18 $ — $ (13 ) $ 5 The portion of the funded status of the plans not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions): Pension Other Postretirement 2016 2015 2016 2015 Net loss $ 15 $ 26 $ 36 $ 42 Prior service cost (credit) 1 2 (31 ) (36 ) Total $ 16 $ 28 $ 5 $ 6
Defined Benefit Plans, Amounts To Be Recognized In Following Year [Table Text Block]	The net loss and prior service cost (credit) that will be amortized in 2017 into net periodic benefit cost are estimated to be as follows (in millions): Net Loss Prior Service Cost (Credit) Total Pension $ 1 $ 1 $ 2 Other postretirement 2 (6 ) (4 ) Total $ 3 $ (5 ) $ (2 )
Plan Assumptions [Table Text Block]	Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Benefit obligations as of December 31: Discount rate 4.10 % 4.50 % 4.00 % 3.90 % 4.25 % 3.75 % Rate of compensation increase 2.75 % 2.75 % 2.75 % N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.50 % 4.00 % 4.75 % 4.25 % 3.75 % 4.50 % Expected return on plan assets (1) 7.00 % 7.25 % 7.50 % 6.75 % 7.00 % 7.25 % Rate of compensation increase 2.75 % 2.75 % 3.00 % N/A N/A N/A (1) Amounts reflected are pre-tax values. Assumed after-tax returns for a taxable, non-union other postretirement plan were 5.00% for 2016 , and 5.18% for 2015 , and 5.37% for 2014 . In establishing its assumption as to the expected return on plan assets, MidAmerican Energy utilizes the asset allocation and return assumptions for each asset class based on historical performance and forward-looking views of the financial markets. 2016 2015 Assumed healthcare cost trend rates as of December 31: Healthcare cost trend rate assumed for next year 7.40 % 7.70 % Rate that the cost trend rate gradually declines to 5.00 % 5.00 % Year that the rate reaches the rate it is assumed to remain at 2025 2025
Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates [Table Text Block]	A one percentage-point change in assumed healthcare cost trend rates would have the following effects (in millions): One Percentage-Point Increase Decrease Increase (decrease) in: Total service and interest cost for the year ended December 31, 2016 $ — $ — Other postretirement benefit obligation as of December 31, 2016 3 (2 )
Expected Benefit Payments [Table Text Block]	Net periodic benefit costs assigned to MidAmerican Energy affiliates are reimbursed currently in accordance with its intercompany administrative services agreement. The expected benefit payments to participants in MidAmerican Energy's pension and other postretirement benefit plans for 2017 through 2021 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Pension Other Postretirement 2017 $ 60 $ 18 2018 60 19 2019 62 20 2020 62 21 2021 60 21 2022-2026 278 97
Allocation of Plan Assets [Table Text Block]	The target allocations (percentage of plan assets) for MidAmerican Energy's pension and other postretirement benefit plan assets are as follows as of December 31, 2016 : Pension Other Postretirement % % Debt securities (1) 20-40 25-45 Equity securities (1) 60-80 50-80 Real estate funds 2-8 — Other 0-5 0-5 (1) For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.
Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following table presents the fair value of plan assets, by major category, for MidAmerican Energy's defined benefit pension plan (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ — $ 17 $ — $ 17 Debt securities: United States government obligations 9 — — 9 Corporate obligations — 53 — 53 Municipal obligations — 6 — 6 Agency, asset and mortgage-backed obligations — 22 — 22 Equity securities: United States companies 130 — — 130 International equity securities 39 — — 39 Investment funds (2) 63 — — 63 Total assets in the hierarchy $ 241 $ 98 $ — 339 Investment funds (2) measured at net asset value 295 Real estate funds measured at net asset value 50 Total assets measured at fair value $ 684 As of December 31, 2015: Cash equivalents $ — $ 16 $ — $ 16 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 57 — 57 Municipal obligations — 6 — 6 Agency, asset and mortgage-backed obligations — 27 — 27 Equity securities: United States companies 130 — — 130 International equity securities 40 — — 40 Investment funds (2) 61 — — 61 Total assets in the hierarchy $ 236 $ 106 $ — 342 Investment funds (2) measured at net asset value 296 Real estate funds measured at net asset value 40 Total assets measured at fair value $ 678 (1) Refer to Note 14 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 74% and 26% , respectively, for 2016 and 72% and 28% , respectively, for 2015 . Additionally, these funds are invested in United States and international securities of approximately 71% and 29% , respectively, for 2016 and 73% and 27% , respectively, for 2015 . The following table presents the fair value of plan assets, by major category, for MidAmerican Energy's defined benefit other postretirement plans (in millions): Input Levels for Fair Value Measurements (1) Level 1 Level 2 Level 3 Total As of December 31, 2016: Cash equivalents $ 10 $ — $ — $ 10 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 11 — 11 Municipal obligations — 37 — 37 Agency, asset and mortgage-backed obligations — 11 — 11 Equity securities: United States companies 122 — — 122 Investment funds (2) 56 — — 56 Total assets measured at fair value $ 193 $ 59 $ — $ 252 As of December 31, 2015: Cash equivalents $ 5 $ — $ — $ 5 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 12 — 12 Municipal obligations — 39 — 39 Agency, asset and mortgage-backed obligations — 12 — 12 Equity securities: United States companies 120 — — 120 Investment funds (2) 56 — — 56 Total assets measured at fair value $ 186 $ 63 $ — $ 249 (1) Refer to Note 14 for additional discussion regarding the three levels of the fair value hierarchy. (2) Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 70% and 30% , respectively, for 2016 and 68% and 32% , respectively, for 2015 . Additionally, these funds are invested in United States and international securities of approximately 30% and 70% , respectively, for 2016 and 32% and 68% , respectively, for 2015 . The following table presents MidAmerican Energy's assets and liabilities recognized on the Balance Sheets and measured at fair value on a recurring basis (in millions): Input Levels for Fair Value Measurements Level 1 Level 2 Level 3 Other (1) Total As of December 31, 2016: Assets: Commodity derivatives $ — $ 9 $ 1 $ (2 ) $ 8 Money market mutual funds (2) 1 — — — 1 Debt securities: United States government obligations 161 — — — 161 International government obligations — 3 — — 3 Corporate obligations — 36 — — 36 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Equity securities: United States companies 250 — — — 250 International companies 5 — — — 5 Investment funds 9 — — — 9 $ 426 $ 52 $ 1 $ (2 ) $ 477 Liabilities - commodity derivatives $ — $ (3 ) $ (3 ) $ 3 $ (3 ) As of December 31, 2015 Assets: Commodity derivatives $ — $ 8 $ 18 $ (13 ) $ 13 Money market mutual funds (2) 56 — — — 56 Debt securities: United States government obligations 133 — — — 133 International government obligations — 2 — — 2 Corporate obligations — 39 — — 39 Municipal obligations — 1 — — 1 Agency, asset and mortgage-backed obligations — 3 — — 3 Auction rate securities — — 26 — 26 Equity securities: United States companies 239 — — — 239 International companies 6 — — — 6 Investment funds 4 — — — 4 $ 438 $ 53 $ 44 $ (13 ) $ 522 Liabilities - commodity derivatives $ (13 ) $ (61 ) $ (24 ) $ 41 $ (57 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $1 million and $28 million as of December 31, 2016 and 2015 , respectively. (2) Amounts are included in cash and cash equivalents and investments and restricted cash and investments on the Balance Sheets. The fair value of these money market mutual funds approximates cost.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Net Benefit Costs [Table Text Block]	Pension and postretirement costs allocated by MidAmerican Funding to its parent and other affiliates in each of the years ended December 31, were as follows (in millions): 2016 2015 2014 Pension costs $ 4 $ 4 $ 4 Other postretirement costs (1 ) (2 ) (2 )

Retirement Plan and Postretir58

Retirement Plan and Postretirement Benefits Retirement Plan and Postretirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2016
Nevada Power Company [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule of Amounts Recognized in Balance Sheet [Table Text Block]	Amounts receivable from (payable to) NV Energy are included on the Consolidated Balance Sheets and consist of the following as of December 31 (in millions): 2016 2015 Qualified Pension Plan - Other long-term liabilities $ (24 ) $ (38 ) Non-Qualified Pension Plans: Other current liabilities (1 ) (1 ) Other long-term liabilities (9 ) (9 ) Other Postretirement Plans - Other long-term liabilities (4 ) (5 )
Sierra Pacific Power Company [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule of Amounts Recognized in Balance Sheet [Table Text Block]	Amounts payable to NV Energy are included on the Consolidated Balance Sheets and consist of the following as of December 31 (in millions): 2016 2015 Qualified Pension Plan - Other long-term liabilities $ (12 ) $ (29 ) Non-Qualified Pension Plans: Other current liabilities (1 ) (1 ) Other long-term liabilities (9 ) (9 ) Other Postretirement Plans - Other long-term liabilities (28 ) (32 )
Domestic Pension Plans [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule of Net Benefit Costs [Table Text Block]	Net periodic benefit cost for the plans included the following components for the years ended December 31 (in millions): Pension Other Postretirement 2016 2015 2014 2016 2015 2014 Service cost $ 29 $ 33 $ 36 $ 9 $ 11 $ 14 Interest cost 126 121 131 31 31 46 Expected return on plan assets (160 ) (169 ) (164 ) (41 ) (45 ) (53 ) Net amortization 46 53 44 (12 ) (11 ) (3 ) Net periodic benefit cost (credit) $ 41 $ 38 $ 47 $ (13 ) $ (14 ) $ 4

Asset Retirement Oblilgations (

Asset Retirement Oblilgations (Tables)	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations By Type [Table Text Block]	The following table presents the Company's ARO liabilities by asset type as of December 31 (in millions): 2016 2015 Fossil fuel facilities $ 404 $ 443 Quad Cities Station 343 289 Wind generating facilities 124 104 Offshore pipeline facilities 33 31 Solar generating facilities 12 12 Other 38 42 Total asset retirement obligations $ 954 $ 921 Quad Cities Station nuclear decommissioning trust funds $ 460 $ 429
Asset Retirement Obligation Disclosure [Table Text Block]	The following table reconciles the beginning and ending balances of the Company's ARO liabilities for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 921 $ 753 Change in estimated costs 33 104 Additions 25 59 Retirements (63 ) (32 ) Accretion 38 37 Ending balance $ 954 $ 921 Reflected as: Other current liabilities $ 98 $ 92 Other long-term liabilities 856 829 Total ARO liability $ 954 $ 921
PacifiCorp [Member]
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligation Disclosure [Table Text Block]	The following table reconciles the beginning and ending balances of PacifiCorp's ARO liabilities for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 224 $ 135 Change in estimated costs 2 62 Additions — 30 Retirements (19 ) (10 ) Accretion 8 7 Ending balance $ 215 $ 224 Reflected as: Other current liabilities $ 21 $ 35 Other long-term liabilities 194 189 $ 215 $ 224
MidAmerican Energy Company [Member]
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations By Type [Table Text Block]	The following table presents MidAmerican Energy's ARO liabilities by asset type as of December 31, (in millions): 2016 2015 Quad Cities Station $ 343 $ 289 Fossil-fueled generating facilities 132 160 Wind-powered generating facilities 91 82 Other 1 1 Total asset retirement obligations $ 567 $ 532 Quad Cities Station nuclear decommissioning trust funds (1) $ 460 $ 429 (1) Refer to Note 7 for a discussion of the Quad Cities Station nuclear decommissioning trust funds.
Asset Retirement Obligation Disclosure [Table Text Block]	The following table reconciles the beginning and ending balances of MidAmerican Energy's ARO liabilities for the years ended December 31, (in millions): 2016 2015 Beginning balance $ 532 $ 460 Change in estimated costs 28 36 Additions 14 22 Retirements (32 ) (9 ) Accretion 25 23 Ending balance $ 567 $ 532 Reflected as: Other current liabilities $ 57 $ 44 Asset retirement obligations 510 488 $ 567 $ 532
Nevada Power Company [Member]
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations By Type [Table Text Block]	The following table presents Nevada Power 's ARO liabilities by asset type as of December 31 (in millions): 2016 2015 Waste water remediation $ 38 $ 42 Evaporative ponds and dry ash landfills 22 27 Asbestos 4 3 Solar 2 2 Other 17 11 Total asset retirement obligations $ 83 $ 85
Asset Retirement Obligation Disclosure [Table Text Block]	The following table reconciles the beginning and ending balances of Nevada Power 's ARO liabilities for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 85 $ 86 Change in estimated costs 4 3 Additions — 3 Retirements (10 ) (11 ) Accretion 4 4 Ending balance $ 83 $ 85 Reflected as: Other current liabilities $ 20 $ 13 Other long-term liabilities 63 72 $ 83 $ 85
Sierra Pacific Power Company [Member]
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations By Type [Table Text Block]	The following table presents Sierra Pacific 's ARO liabilities by asset type as of December 31 (in millions): 2016 2015 Asbestos $ 4 $ 4 Evaporative ponds and dry ash landfills 3 3 Other 3 3 Total asset retirement obligations $ 10 $ 10
Asset Retirement Obligation Disclosure [Table Text Block]	The following table reconciles the beginning and ending balances of Sierra Pacific 's ARO liabilities for the years ended December 31 (in millions): 2016 2015 Beginning balance $ 10 $ 11 Retirements — (1 ) Ending balance $ 10 $ 10 Reflected as: Other current liabilities $ — $ — Other long-term liabilities 10 10 $ 10 $ 10

Commitments and Contingencies60

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2016
Contractual Obligation [Line Items]
Contractual Obligation, Fiscal Year Maturity Schedule	The Company has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31, 2016 are as follows (in millions): 2022 and 2017 2018 2019 2020 2021 Thereafter Total Contract type: Fuel, capacity and transmission contract commitments $ 2,370 $ 1,606 $ 1,389 $ 1,208 $ 1,010 $ 10,053 $ 17,636 Construction commitments 852 49 66 1 1 4 973 Operating leases and easements 141 122 101 87 73 1,085 1,609 Maintenance, service and other contracts 303 220 212 186 180 723 1,824 $ 3,666 $ 1,997 $ 1,768 $ 1,482 $ 1,264 $ 11,865 $ 22,042
PacifiCorp [Member]
Contractual Obligation [Line Items]
Contractual Obligation, Fiscal Year Maturity Schedule	PacifiCorp has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31, 2016 are as follows (in millions): 2017 2018 2019 2020 2021 2022 and Thereafter Total Contract type: Purchased electricity contracts - commercially operable $ 253 $ 160 $ 157 $ 157 $ 145 $ 1,630 $ 2,502 Purchased electricity contracts - non-commercially operable 10 13 17 17 18 390 465 Fuel contracts 796 616 596 507 346 1,407 4,268 Construction commitments 62 46 26 4 1 4 143 Transmission 109 106 90 61 47 467 880 Operating leases and easements 5 5 5 5 4 39 63 Maintenance, service and other contracts 53 29 31 17 20 68 218 Total commitments $ 1,288 $ 975 $ 922 $ 768 $ 581 $ 4,005 $ 8,539
MidAmerican Energy Company [Member]
Contractual Obligation [Line Items]
Contractual Obligation, Fiscal Year Maturity Schedule	MidAmerican Energy had the following firm commitments that are not reflected on the Balance Sheet. Minimum payments as of December 31, 2016 , are as follows (in millions): 2022 and 2017 2018 2019 2020 2021 Thereafter Total Contract type: Coal and natural gas for generation $ 141 $ 73 $ 40 $ — $ — $ — $ 254 Electric capacity and transmission 37 29 29 28 25 59 207 Natural gas contracts for gas operations 137 34 13 12 10 23 229 Construction commitments 347 2 5 — — — 354 Easements and operating leases 20 20 20 19 19 624 722 Maintenance and services contracts 72 90 91 92 86 210 641 $ 754 $ 248 $ 198 $ 151 $ 140 $ 916 $ 2,407
Nevada Power Company [Member]
Contractual Obligation [Line Items]
Contractual Obligation, Fiscal Year Maturity Schedule	Nevada Power has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31 , 2016 are as follows (in millions): 2017 2018 2019 2020 2021 2022 and Thereafter Total Contract type: Fuel, capacity and transmission contract commitments $ 697 $ 445 $ 352 $ 355 $ 358 $ 5,310 $ 7,517 Fuel and capacity contract commitments (not commercially operable) 7 14 29 36 37 683 806 Operating leases and easements 9 9 8 7 7 51 91 Maintenance, service and other contracts 118 39 37 37 36 75 342 Total commitments $ 831 $ 507 $ 426 $ 435 $ 438 $ 6,119 $ 8,756
Sierra Pacific Power Company [Member]
Contractual Obligation [Line Items]
Contractual Obligation, Fiscal Year Maturity Schedule	Sierra Pacific has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31 , 2016 are as follows (in millions): 2022 and 2017 2018 2019 2020 2021 Thereafter Total Contract type: Fuel, capacity and transmission contract commitments $ 238 $ 156 $ 103 $ 71 $ 62 $ 375 $ 1,005 Fuel and capacity contract commitments (not commercially operable) 5 10 10 11 11 215 262 Operating leases and easements 4 4 3 3 3 46 63 Maintenance, service and other contracts 4 5 4 6 6 17 42 Total commitments $ 251 $ 175 $ 120 $ 91 $ 82 $ 653 $ 1,372

Components of Accumulated Oth61

Components of Accumulated Other Comprehensive Loss, Net (Tables)	12 Months Ended
	Dec. 31, 2016
Schedule of accumulated other comprehensive income (loss)
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table shows the change in accumulated other comprehensive loss attributable to BHE shareholders by each component of other comprehensive income (loss), net of applicable income taxes, for the year ended December 31, (in millions): Accumulated Unrealized Other Unrecognized Foreign Gains on Unrealized Comprehensive Amounts on Currency Available- Gains on Loss Attributable Retirement Translation For-Sale Cash Flow To BHE Benefits Adjustment Securities Hedges Shareholders, Net Balance, December 31, 2013 $ (559 ) $ (98 ) $ 524 $ 36 $ (97 ) Other comprehensive income 69 (314 ) (134 ) (18 ) (397 ) Balance, December 31, 2014 (490 ) (412 ) 390 18 (494 ) Other comprehensive income (loss) 52 (680 ) 225 (11 ) (414 ) Balance, December 31, 2015 (438 ) (1,092 ) 615 7 (908 ) Other comprehensive income (loss) (9 ) (583 ) (30 ) 19 (603 ) Balance, December 31, 2016 $ (447 ) $ (1,675 ) $ 585 $ 26 $ (1,511 )
MidAmerican Energy Company [Member]
Schedule of accumulated other comprehensive income (loss)
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table shows the change in accumulated other comprehensive loss by each component of other comprehensive income, net of applicable income taxes, for the years ended December 31, 2016 and 2015 (in millions): Unrealized Unrealized Accumulated Losses on Losses Other Available-For-Sale on Cash Flow Comprehensive Securities Hedges Loss, Net Balance, December 31, 2014 $ (3 ) $ (20 ) $ (23 ) Other comprehensive loss — (7 ) (7 ) Balance, December 31, 2015 $ (3 ) $ (27 ) $ (30 ) Other comprehensive income 3 — 3 Dividend (Note 3) — 27 27 Balance, December 31, 2016 $ — $ — $ —

Noncontrolling Interests Noncon

Noncontrolling Interests Noncontrolling Interests (Tables)	12 Months Ended
	Dec. 31, 2016
MidAmerican Funding, LLC and Subsidiaries [Domain]
Noncontrolling Interest [Line Items]
Schedule of Other Nonoperating Income (Expense) [Table Text Block]	as shown on the Consolidated Statements of Operations, includes the following other income (expense) items for the years ended December 31 (in millions): 2016 2015 2014 Corporate-owned life insurance income $ 8 $ 4 $ 8 Gain on redemption of auction rate securities 5 — — Gains on sales of assets and other investments 3 13 — Leveraged leases — 1 5 Other, net 3 1 5 Total $ 19 $ 19 $ 18 MidAmerican Funding recognized a $13 million pre-tax gain on the sale of an investment in a generating facility lease in 2015.

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	Information related to the Company's reportable segments is shown below (in millions): Years Ended December 31, 2016 2015 2014 Operating revenue: PacifiCorp $ 5,201 $ 5,232 $ 5,252 MidAmerican Funding 2,631 2,515 2,844 NV Energy 2,895 3,351 3,241 Northern Powergrid 995 1,140 1,283 BHE Pipeline Group 978 1,016 1,078 BHE Transmission 502 592 62 BHE Renewables 743 728 623 HomeServices 2,801 2,526 2,144 BHE and Other (1) 676 780 799 Total operating revenue $ 17,422 $ 17,880 $ 17,326 Depreciation and amortization: PacifiCorp $ 783 $ 780 $ 745 MidAmerican Funding 479 407 351 NV Energy 421 410 379 Northern Powergrid 200 202 198 BHE Pipeline Group 206 204 196 BHE Transmission 241 185 13 BHE Renewables 230 216 152 HomeServices 31 29 29 BHE and Other (1) — (5 ) (6 ) Total depreciation and amortization $ 2,591 $ 2,428 $ 2,057 Operating income: PacifiCorp $ 1,427 $ 1,344 $ 1,308 MidAmerican Funding 566 451 395 NV Energy 770 812 791 Northern Powergrid 494 593 674 BHE Pipeline Group 455 464 439 BHE Transmission 92 260 16 BHE Renewables 256 255 314 HomeServices 212 184 125 BHE and Other (1) (21 ) (35 ) (16 ) Total operating income 4,251 4,328 4,046 Interest expense (1,854 ) (1,904 ) (1,711 ) Capitalized interest 139 74 89 Allowance for equity funds 158 91 98 Interest and dividend income 120 107 38 Other, net 36 39 42 Total income before income tax expense and equity income (loss) $ 2,850 $ 2,735 $ 2,602 Years Ended December 31, 2016 2015 2014 Interest expense: PacifiCorp $ 381 $ 383 $ 386 MidAmerican Funding 218 206 197 NV Energy 250 262 283 Northern Powergrid 136 145 151 BHE Pipeline Group 50 66 76 BHE Transmission 153 146 14 BHE Renewables 198 193 175 HomeServices 2 3 4 BHE and Other (1) 466 500 425 Total interest expense $ 1,854 $ 1,904 $ 1,711 Income tax expense (benefit): PacifiCorp $ 341 $ 328 $ 310 MidAmerican Funding (139 ) (150 ) (122 ) NV Energy 200 207 195 Northern Powergrid 22 35 110 BHE Pipeline Group 163 158 149 BHE Transmission 26 63 28 BHE Renewables (32 ) 41 65 HomeServices 81 72 44 BHE and Other (1) (259 ) (304 ) (190 ) Total income tax expense (benefit) $ 403 $ 450 $ 589 Capital expenditures: PacifiCorp $ 903 $ 916 $ 1,066 MidAmerican Funding 1,637 1,448 1,527 NV Energy 529 571 558 Northern Powergrid 579 674 675 BHE Pipeline Group 226 240 257 BHE Transmission 466 966 222 BHE Renewables 719 1,034 2,221 HomeServices 20 16 17 BHE and Other 11 10 12 Total capital expenditures $ 5,090 $ 5,875 $ 6,555 As of December 31, 2016 2015 2014 Property, plant and equipment, net: PacifiCorp $ 19,162 $ 19,039 $ 18,755 MidAmerican Funding 12,835 11,737 10,535 NV Energy 9,825 9,767 9,648 Northern Powergrid 5,148 5,790 5,599 BHE Pipeline Group 4,423 4,345 4,286 BHE Transmission 5,810 5,301 5,567 BHE Renewables 5,302 4,805 4,897 HomeServices 78 70 68 BHE and Other (74 ) (85 ) (107 ) Total property, plant and equipment, net $ 62,509 $ 60,769 $ 59,248 Total assets: PacifiCorp $ 23,563 $ 23,550 $ 23,404 MidAmerican Funding 17,571 16,315 15,164 NV Energy 14,320 14,656 14,256 Northern Powergrid 6,433 7,317 7,059 BHE Pipeline Group 5,144 4,953 4,951 BHE Transmission 8,378 7,553 7,979 BHE Renewables 7,010 5,892 6,082 HomeServices 1,776 1,705 1,622 BHE and Other 1,245 1,677 1,299 Total assets $ 85,440 $ 83,618 $ 81,816 Years Ended December 31, 2016 2015 2014 Operating revenue by country: United States $ 15,895 $ 16,121 $ 15,857 United Kingdom 995 1,140 1,281 Canada 506 600 78 Philippines and other 26 19 110 Total operating revenue by country $ 17,422 $ 17,880 $ 17,326 Income before income tax expense and equity income by country: United States $ 2,264 $ 2,034 $ 2,001 United Kingdom 382 472 557 Canada 135 165 4 Philippines and other 69 64 40 Total income before income tax expense and equity income by country: $ 2,850 $ 2,735 $ 2,602 As of December 31, 2016 2015 2014 Property, plant and equipment, net by country: United States $ 51,671 $ 49,680 $ 47,918 United Kingdom 5,020 5,757 5,563 Canada 5,803 5,298 5,570 Philippines and other 15 34 197 Total property, plant and equipment, net by country $ 62,509 $ 60,769 $ 59,248 (1) The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other , relate to other corporate entities, including MidAmerican Energy Services, LLC, corporate functions and intersegment eliminations.
Schedule of Goodwill [Table Text Block]	The following table shows the change in the carrying amount of goodwill by reportable segment for the years ended December 31, 2016 and 2015 (in millions): BHE BHE MidAmerican NV Northern Pipeline BHE BHE Home- and PacifiCorp Funding Energy Powergrid Group Transmission Renewables Services Other Total December 31, 2014 $ 1,129 $ 2,102 $ 2,369 $ 1,100 $ 127 $ 1,657 $ 95 $ 761 $ 3 $ 9,343 Acquisitions — — — — — 44 — 33 — 77 Foreign currency translation — — — (44 ) — (273 ) — — (1 ) (318 ) Other — — — — (26 ) — — — — (26 ) December 31, 2015 1,129 2,102 2,369 1,056 101 1,428 95 794 2 9,076 Acquisitions — — — — — 4 — 46 — 50 Foreign currency translation — — — (126 ) — 42 — — (2 ) (86 ) Other — — — — (26 ) (4 ) — — — (30 ) December 31, 2016 $ 1,129 $ 2,102 $ 2,369 $ 930 $ 75 $ 1,470 $ 95 $ 840 $ — $ 9,010
MidAmerican Energy Company [Member]
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	The following tables provide information on a reportable segment basis (in millions): Years Ended December 31, 2016 2015 2014 Operating revenue: Regulated electric $ 1,985 $ 1,837 $ 1,817 Regulated gas 637 661 996 Other 3 4 9 Total operating revenue $ 2,625 $ 2,502 $ 2,822 Depreciation and amortization: Regulated electric $ 436 $ 366 $ 312 Regulated gas 43 41 39 Total depreciation and amortization $ 479 $ 407 $ 351 Operating income: Regulated electric $ 497 $ 385 $ 319 Regulated gas 68 64 75 Total operating income $ 565 $ 449 $ 394 Interest expense: Regulated electric $ 178 $ 166 $ 157 Regulated gas 18 17 17 Total interest expense $ 196 $ 183 $ 174 Income tax (benefit) expense from continuing operations: Regulated electric $ (156 ) $ (163 ) $ (138 ) Regulated gas 22 16 22 Other 2 — — Total income tax (benefit) expense from continuing operations $ (132 ) $ (147 ) $ (116 ) Net income: Regulated electric $ 512 $ 413 $ 361 Regulated gas 32 33 40 Other (2 ) — — Income from continuing operations 542 446 401 Income on discontinued operations — 16 16 Net income $ 542 $ 462 $ 417 Years Ended December 31, 2016 2015 2014 Utility construction expenditures: Regulated electric $ 1,564 $ 1,365 $ 1,429 Regulated gas 72 81 97 Total utility construction expenditures $ 1,636 $ 1,446 $ 1,526 As of December 31, 2016 2015 2014 Total assets: Regulated electric $ 14,113 $ 12,970 $ 11,850 Regulated gas 1,345 1,251 1,217 Other 1 164 167 Total assets $ 15,459 $ 14,385 $ 13,234
MidAmerican Funding, LLC and Subsidiaries [Domain]
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	The following tables provide information on a reportable segment basis (in millions): Years Ended December 31, 2016 2015 2014 Operating revenue: Regulated electric $ 1,985 $ 1,837 $ 1,817 Regulated gas 637 661 996 Other 9 17 31 Total operating revenue $ 2,631 $ 2,515 $ 2,844 Depreciation and amortization: Regulated electric $ 436 $ 366 $ 312 Regulated gas 43 41 39 Total depreciation and amortization $ 479 $ 407 $ 351 Operating income: Regulated electric $ 497 $ 385 $ 319 Regulated gas 68 64 75 Other 1 2 1 Total operating income $ 566 $ 451 $ 395 Interest expense: Regulated electric $ 178 $ 166 $ 157 Regulated gas 18 17 17 Other 23 23 23 Total interest expense $ 219 $ 206 $ 197 Income tax (benefit) expense from continuing operations: Regulated electric $ (156 ) $ (163 ) $ (138 ) Regulated gas 22 16 22 Other (5 ) (3 ) (6 ) Total income tax (benefit) expense from continuing operations $ (139 ) $ (150 ) $ (122 ) Net income: Regulated electric $ 512 $ 413 $ 361 Regulated gas 32 33 40 Other (12 ) (4 ) (8 ) Income from continuing operations 532 442 393 Income on discontinued operations — 16 16 Net income $ 532 $ 458 $ 409 Utility construction expenditures: Regulated electric $ 1,564 $ 1,365 $ 1,429 Regulated gas 72 81 97 Total utility construction expenditures $ 1,636 $ 1,446 $ 1,526 As of December 31, 2016 2015 2014 Total assets: Regulated electric $ 15,304 $ 14,161 $ 13,041 Regulated gas 1,424 1,330 1,296 Other 19 183 185 Total assets $ 16,747 $ 15,674 $ 14,522
Schedule of Goodwill [Table Text Block]	Goodwill by reportable segment as of December 31, 2016 and 2015 , was as follows (in millions): Regulated electric $ 1,191 Regulated gas 79 Total $ 1,270
Sierra Pacific Power Company [Member]
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	The following tables provide information on a reportable segment basis for the years ended December 31 (in millions): Years Ended December 31, 2016 2015 2014 Operating revenue: Regulated electric $ 702 $ 810 $ 779 Regulated gas 110 137 125 Total operating revenue $ 812 $ 947 $ 904 Cost of sales: Regulated electric $ 265 $ 374 $ 361 Regulated gas 55 84 76 Total cost of sales $ 320 $ 458 $ 437 Gross margin: Regulated electric $ 437 $ 436 $ 418 Regulated gas 55 53 49 Total gross margin $ 492 $ 489 $ 467 Operating and maintenance: Regulated electric $ 153 $ 149 $ 143 Regulated gas 17 18 19 Total operating and maintenance $ 170 $ 167 $ 162 Depreciation and amortization: Regulated electric $ 101 $ 96 $ 90 Regulated gas 17 17 15 Total depreciation and amortization $ 118 $ 113 $ 105 Operating income: Regulated electric $ 161 $ 168 $ 165 Regulated gas 19 16 13 Total operating income $ 180 $ 184 $ 178 Interest expense: Regulated electric $ 49 $ 56 $ 57 Regulated gas 5 5 4 Total interest expense $ 54 $ 61 $ 61 Income tax expense: Regulated electric $ 44 $ 43 $ 43 Regulated gas 5 4 4 Total income tax expense $ 49 $ 47 $ 47 Years Ended December 31, 2016 2015 2014 Capital expenditures: Regulated electric $ 176 $ 229 $ 168 Regulated gas 18 23 18 Total capital expenditures $ 194 $ 252 $ 186 As of December 31, Total assets: 2016 2015 2014 Regulated electric $ 3,119 $ 3,060 $ 2,984 Regulated gas 314 316 322 Regulated common assets (1) 60 111 30 Total assets $ 3,493 $ 3,487 $ 3,336 (1) Consists principally of cash and cash equivalents not included in either the regulated electric or regulated natural gas segments.

Unaudited Quarterly Operating64

Unaudited Quarterly Operating Results Unaudited Quarterly Operating Results (Tables)	12 Months Ended
	Dec. 31, 2016
MidAmerican Energy Company [Member]
Quarterly Operating Results [Line Items]
Schedule of Quarterly Financial Information [Table Text Block]	2016 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 625 $ 584 $ 795 $ 621 Operating income 100 139 284 42 Net income 76 131 320 15 2015 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 722 $ 572 $ 680 $ 528 Operating income 100 112 208 29 Income from continuing operations 90 126 233 (3 ) Income on discontinued operations 4 5 1 6 Net income 94 131 234 3 Quarterly data reflect seasonal variations common to a Midwest utility.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Quarterly Operating Results [Line Items]
Schedule of Quarterly Financial Information [Table Text Block]	2016 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 626 $ 585 $ 797 $ 623 Operating income 100 140 284 42 Net income 73 127 318 14 2015 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 727 $ 576 $ 681 $ 531 Operating income 101 112 209 29 Income from continuing operations 95 124 230 (7 ) Income on discontinued operations 4 5 1 6 Net income 99 129 231 (1 ) Quarterly data reflect seasonal variations common to a Midwest utility.
Nevada Power Company [Member]
Quarterly Operating Results [Line Items]
Schedule of Quarterly Financial Information [Table Text Block]	Three-Month Periods Ended March 31, June 30, September 30, December 31, 2016 2016 2016 2016 Operating revenues $ 399 $ 525 $ 766 $ 393 Operating income 46 141 324 69 Net income 3 66 188 22 Three-Month Periods Ended March 31, June 30, September 30, December 31, 2015 2015 2015 2015 Operating revenues $ 459 $ 607 $ 878 $ 458 Operating income 74 136 329 74 Net income 24 60 187 17
Sierra Pacific Power Company [Member]
Quarterly Operating Results [Line Items]
Schedule of Quarterly Financial Information [Table Text Block]	Three-Month Periods Ended March 31, June 30, September 30, December 31, 2016 2016 2016 2016 Regulated electric operating revenue $ 170 $ 162 $ 207 $ 163 Regulated natural gas operating revenue 47 19 15 29 Operating income 41 28 69 42 Net income 17 10 38 19 Three-Month Periods Ended March 31, June 30, September 30, December 31, 2015 2015 2015 2015 Regulated electric operating revenue $ 196 $ 201 $ 228 $ 185 Regulated natural gas operating revenue 50 26 18 43 Operating income 43 37 66 38 Net income 19 16 33 15

Discontinued Operations Disco65

Discontinued Operations Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2016
MidAmerican Energy Company [Member] | Unregulated Retail Services [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Groups, Including Discontinued Operations [Table Text Block]	Significant line items constituting pre-tax income from discontinued operations and total cash flows from operating activities for the years ended December 31 are as follows (in millions): 2015 2014 Operating revenue $ 905 $ 918 Cost of sales $ 854 $ 863 Cash flows from operating activities $ 30 $ (22 ) Assets, liabilities and equity of the unregulated retail services business reflected in the Balance Sheets as of December 31, 2015 are as follows (in millions): Receivables $ 115 Derivative assets 41 Deferred income taxes 21 Accounts payable (49 ) Derivative liabilities (42 ) Other assets and liabilities, net 4 Accumulated other comprehensive loss, net 27 Equity, excluding accumulated other comprehensive loss, net (117 )

Organization and Operations (De

Organization and Operations (Details)	12 Months Ended
	Dec. 31, 2016OperatingSegmentsOwnedAndOperatedCompanies
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of Reportable Segments | OperatingSegments	8
Number of owned and operated utility companies in the United States	4
Number of states owned and operated utility companies serve customers	11
Number of owned and operated electricity distribution companies in Great Britain	2
Number of owned and operated interstate natural gas pipeline companies in the United States	2
Number of owned and operated electricity transmission companies in Canada	1
Number of owned and operated renewable energy businesses	1
Number of owned and operated residential real estate brokerage firms in the United States	1
Number of owned and operated real estate franchise networks in the United States	1

Summary of Significant Accoun67

Summary of Significant Accounting Policies - Allowance for Doubtful Accounts (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Allowance for Doubtful Accounts [Line Items]
Allowance for doubtful accounts	$ 33	$ 31

Summary of Significant Accoun68

Summary of Significant Accounting Policies - Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Summary of Significant Accounting Policies - Inventory [Abstract]
Energy Related Inventory, Other Fossil Fuel	$ 402	$ 353
Inventory, Raw Materials and Supplies, Gross	523	529
Replacement cost of inventory	$ 27	$ 8

Summary of Significant Accoun69

Summary of Significant Accounting Policies - Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Significant Accounting Policies - Revenue Recognition [Abstract]
Unbilled revenue	$ 643	$ 660

Summary of Significant Accoun70

Summary of Significant Accounting Policies - Income Taxes (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Significant Accounting Policies - Income Taxes [Abstract]
Regulatory asset, deferred income taxes	$ 1,600	$ 1,500
Regulatory liability, deferred income taxes	25	$ 29
Undistributed earnings of foreign subsidiaries	$ 3,000

Summary of Significant Accoun71

Summary of Significant Accounting Policies New Accounting Pronouncements (Details) - BHE - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Jan. 01, 2015
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification	$ (30)	$ 225	$ (134)
Retained Earnings [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets				$ 56
Noncontrolling Interest [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets				$ 11

Summary of SIgnificant Accoun72

Summary of SIgnificant Accounting Policies - PacifiCorp - Investments (Details) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
PacifiCorp [Member]
Unrealized gains and losses on available-for-sale securities	$ 0	$ 0

Summary of Significant Accoun73

Summary of Significant Accounting Policies - PacifiCorp - Allowance for Doubtful Accounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Valuation and Qualifying Accounts Disclosure [Line Items]
Beginning balance	$ 31
Ending balance	33	$ 31
PacifiCorp [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Beginning balance	7	7
Ending balance	7	7	$ 7
Allowance for Doubtful Accounts [Member] | PacifiCorp [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Beginning balance	7	7	8
Charged to operating costs and expenses, net	12	10	11
Write-offs, net	$ 12	10	12
Ending balance		$ 7	$ 7

Summary of Significant Accoun74

Summary of Significant Accounting Policies - PacifiCorp - Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Unbilled revenue	$ 643	$ 660
PacifiCorp [Member]
Unbilled revenue	$ 275	$ 245

Summary of Significant Accoun75

Summary of Significant Accounting Policies - PacifiCorp - Income Taxes (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Assets and Liabilities [Line Items]
Total regulatory assets		$ 4,457	$ 4,285
Regulatory Liabilities		3,120	3,033
Deferred Income Tax Charge [Member]
Deferred Tax Assets and Liabilities [Line Items]
Total regulatory assets	[1]	1,754	1,577
PacifiCorp [Member]
Deferred Tax Assets and Liabilities [Line Items]
Total regulatory assets		1,543	1,685
Regulatory Liabilities		1,032	972
Deferred investment tax credit		18	23
PacifiCorp [Member] | Deferred Income Tax Charge [Member]
Deferred Tax Assets and Liabilities [Line Items]
Total regulatory assets	[2]	421	437
PacifiCorp [Member] | Deferred Income Tax Charge [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory Liabilities		$ 9	$ 12
[1]	Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
[2]	(1)Amounts primarily represent income tax benefits and expense related to certain property-related basis differences and other various items that PacifiCorp is required to pass on to its customers.

Summary of Significant Accoun76

Summary of Significant Accounting Policies - MEC - Allowance for Doubtful Accounts (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Valuation and Qualifying Accounts Disclosure [Line Items]
Allowance for Doubtful Accounts Receivable, Current	$ 33	$ 31
MidAmerican Energy Company [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Allowance for Doubtful Accounts Receivable, Current	$ 7	$ 6

Summary of Significant Accoun77

Summary of Significant Accounting Policies - MEC - Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	$ 523	$ 529
Replacement cost of inventory	27	8
MidAmerican Energy Company [Member]
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	99	105
Public utility inventory, coal	137	102
Public utility inventory - natural gas in storage	24	27
Replacement cost of inventory	$ 27	$ 8

Summary of Significant Accoun78

Summary of Significant Accounting Policies - MEC - Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Unbilled revenue	$ 643	$ 660
MidAmerican Energy Company [Member]
Unbilled revenue	87	138
Adjustment clause accounts receivable (payable)	$ 31	$ 17

Summary of Significant Accoun79

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - MEC - Income Taxes (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Assets and Liabilities [Line Items]
Regulatory assets		$ 4,307	$ 4,155
MidAmerican Energy Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory assets		1,161	1,044
Deferred Income Tax Charge [Member] | MidAmerican Energy Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory assets	[1]	$ 985	$ 858
[1]	(1)Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.

Summary of Significant Accoun80

Summary of Significant Accounting Policies - MidAmerican Funding - Goodwill (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
MidAmerican Funding, LLC and Subsidiaries [Domain]
Goodwill [Line Items]
Goodwill impairment	$ 0	$ 0	$ 0

Summary of Significant Accoun81

Summary of Significant Accounting Policies - NPC - Allowance for Doubtful Accounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Allowance for Doubtful Accounts [Line Items]
Beginning balance	$ 31
Ending balance	33	$ 31
Nevada Power Company [Member] | Allowance for Doubtful Accounts [Member]
Allowance for Doubtful Accounts [Line Items]
Beginning balance	13	14	$ 8
Charged to operating costs and expenses, net	16	16	14
Write-offs, net	17	17	8
Ending balance	$ 12	$ 13	$ 14

Summary of Significant Accoun82

Summary of Significant Accounting Policies - NPC - Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	$ 523	$ 529
Energy Related Inventory, Other Fossil Fuel	402	353
Nevada Power Company [Member]
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	60
Energy Related Inventory, Other Fossil Fuel	$ 13	$ 22

Summary of Significant Accoun83

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - NPC - Property, Plant and Equipment, Net (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Nevada Power Company [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Allowance for Funds Used During Construction, Rate	8.09%	8.09%

Summary of Significant Accoun84

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - NPC - Income Taxes (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Assets and Liabilities [Line Items]
Regulatory asset, deferred income taxes	$ 1,600	$ 1,500
Regulatory liability, deferred income taxes	25	29
Nevada Power Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory asset, deferred income taxes	141	149
Regulatory liability, deferred income taxes	$ 9	$ 10

Summary of Significant Accoun85

Summary of Significant Accounting Policies - NPC - Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Unbilled Receivables, Current	$ 643	$ 660
Nevada Power Company [Member]
Unbilled Receivables, Current	$ 91	$ 116

Summary of Significant Accoun86

Summary of Significant Accounting Policies - SPPC - Allowance for Doubtful Accounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Allowance for Doubtful Accounts [Line Items]
Beginning balance	$ 31
Ending balance	33	$ 31
Sierra Pacific Power Company [Member] | Allowance for Doubtful Accounts [Member]
Allowance for Doubtful Accounts [Line Items]
Beginning balance	1	2	$ 1
Charged to operating costs and expenses, net	2	1	2
Write-offs, net	1	2	1
Ending balance	$ 2	$ 1	$ 2

Summary of Significant Accoun87

Summary of Significant Accounting Policies - SPPC - Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	$ 523	$ 529
Energy Related Inventory, Other Fossil Fuel	402	353
Sierra Pacific Power Company [Member]
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	36	34
Energy Related Inventory, Other Fossil Fuel	$ 9	$ 5

Summary of Significant Accoun88

Summary of Significant Accounting Policies - SPPC - Property, Plant and Equipment, Net (Details) - Sierra Pacific Power Company [Member]	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Electricity Generation Plant, Non-Nuclear [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Allowance for Funds Used During Construction, Rate	7.62%	7.62%
Natural Gas Processing Plant [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Allowance for Funds Used During Construction, Rate	6.02%	5.97%
Common Facilities [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Allowance for Funds Used During Construction, Rate	7.44%	7.44%

Summary of Significant Accoun89

Summary of Significant Accounting Policies - SPPC - Income Taxes (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Assets and Liabilities [Line Items]
Regulatory asset, deferred income taxes	$ 1,600	$ 1,500
Regulatory liability, deferred income taxes	25	29
Sierra Pacific Power Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory asset, deferred income taxes	85	90
Regulatory liability, deferred income taxes	$ 6	$ 7

Summary of Significant Accoun90

Summary of Significant Accounting Policies - SPPC - Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Unbilled revenue	$ 643	$ 660
Sierra Pacific Power Company [Member]
Unbilled revenue	$ 52	$ 59

Business Acquisitions (Details)

Business Acquisitions (Details) $ in Millions, CAD in Billions	1 Months Ended	12 Months Ended
	Dec. 31, 2014USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)substationmi	Dec. 31, 2014USD ($)	Dec. 01, 2014CAD
Business Acquisition [Line Items]
Acquisition, net of cash acquired		$ (66)	$ (164)	$ (2,956)
Goodwill	$ 9,343	9,010	9,076	9,343
Goodwill, acquired during period		50	77
Par value		36,295
Net income attributable to BHE shareholders		2,542	$ 2,370	2,095
AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Net assets acquired | CAD					CAD 3.1
Transmission Line | mi			8,200
Substation | substation			300
Other acquisitions [Member]
Business Acquisition [Line Items]
Acquisition, net of cash acquired		(66)	$ (164)	$ (243)
Business combination, recognized identifiable assets acquired and liabilities assumed, liabilities		54	84
CE Generation Transaction [Member]
Business Acquisition [Line Items]
Business acquisition, percentage of voting interests acquired	50.00%			50.00%
Property, plant, and equipment assumed	$ 641			$ 641
Subsidiary debt, less current portion assumed	231			231
Deferred income taxes assumed	170			170
Goodwill, acquired during period		50	33	80
AltaLink [Member]
Business Acquisition [Line Items]
Net income attributable to BHE shareholders			13
NV Energy, Inc. [Member]
Business Acquisition [Line Items]
Goodwill	2,369	2,369	2,369	$ 2,369
Goodwill, acquired during period		$ 0	0
BHE [Member] | AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs			$ 3
Common Stock [Member] | AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Business acquisition, percentage of voting interests acquired					100.00%
Junior Subordinated Debt [Member] | AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Payments to acquire businesses, gross	1,500
Commercial Paper [Member] | AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Payments to acquire businesses, gross	$ 1,000

Property, Plant and Equipment92

Property, Plant and Equipment, Net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 62,509	$ 60,769	$ 59,248
Regulated Operation [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	78,478	76,003
Accumulated depreciation and amortization	(23,603)	(22,682)
Property, plant and equipment in service, net	54,875	53,321
Construction work-in-progress	1,800	2,300
Regulated Operation [Member] | Utility generation, distribution and transmission system [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 71,536	69,248
Regulated Operation [Member] | Utility generation, distribution and transmission system [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Regulated Operation [Member] | Utility generation, distribution and transmission system [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	80 years
Regulated Operation [Member] | Interstate natural gas pipeline assets [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 6,942	6,755
Regulated Operation [Member] | Interstate natural gas pipeline assets [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	3 years
Regulated Operation [Member] | Interstate natural gas pipeline assets [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	80 years
Nonregulated Operation [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 6,596	5,626
Accumulated depreciation and amortization	(1,060)	(805)
Property, plant and equipment in service, net	5,536	4,821
Nonregulated Operation [Member] | Independent power plants [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	5,594	4,751
Nonregulated Operation [Member] | Other assets [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	1,002	875
Common Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment in service, net	60,411	58,142
Construction work-in-progress	2,098	2,627
Property, plant and equipment, net	$ 62,509	60,769
Nonregulated Operation [Member] | Independent power plants [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Nonregulated Operation [Member] | Independent power plants [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years
Nonregulated Operation [Member] | Other assets [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	3 years
Nonregulated Operation [Member] | Other assets [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years
PacifiCorp [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 19,162	19,039	18,755
MidAmerican Funding [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 12,835	$ 11,737	$ 10,535

Property, Plant and Equipment93

Property, Plant and Equipment, Net - PacifiCorp (Details) - PacifiCorp [Member] - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross		$ 27,298	$ 26,757
Public utility accumulated depreciation and amortization		(8,793)	(8,360)
Public Utilities Property, Plant And Equipment In Service, Net		18,505	18,397
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		657	629
Public Utilities, Property, Plant and Equipment, Net		$ 19,162	$ 19,026
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service		2.90%	2.90%	3.00%
Public Utilities, Property, Plant and Equipment, Amount of Acquisition Adjustments		$ 156	$ 155
Public Utilities, Property, Plant and Equipment, Amount of Acquisition Adjustments, Related Accumulated Depreciation		$ 117	112
Minimum [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life		14 years
Public Utilities, Property, Plant and Equipment, Transmission, Useful Life		58 years
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life		20 years
Finite-Lived Intangible Asset, Useful Life	[1]	5 years
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life		5 years
Maximum [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life		67 years
Public Utilities, Property, Plant and Equipment, Transmission, Useful Life		75 years
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life		70 years
Finite-Lived Intangible Asset, Useful Life	[1]	62 years
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life		60 years
Electricity Generation Plant, Non-Nuclear [Member]
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross		$ 12,371	12,164
Electric Transmission [Member]
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross		6,055	5,914
Electric Distribution [Member]
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross		6,590	6,408
Other Intangible Assets [Member]
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross	[1]	884	875
Other Capitalized Property Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross		$ 1,398	$ 1,396
Computer Software, Intangible Asset [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Finite-Lived Intangible Asset, Useful Life		5 years
Computer Software, Intangible Asset [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Finite-Lived Intangible Asset, Useful Life		10 years
[1]	(1)Computer software costs included in intangible plant are initially assigned a depreciable life of 5 to 10 years.

Property, Plant and Equipment94

Property, Plant and Equipment, Net Property, Plant and Equipment - MEC (Details) - MidAmerican Energy Company [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	$ 12,328	$ 11,056
Public Utilities, Property, Plant and Equipment, Net	$ 12,821	$ 11,723
Regulated Electric [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	2.80%	3.00%	2.80%
Natural Gas Processing Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	2.90%	2.90%	2.80%
Regulated Operation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Plant in Service, Excluding Construction Work In Progress	$ 17,770	$ 16,275
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(5,448)	(5,229)
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	12,322	11,046
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	493	667
Regulated Operation [Member] | Electric Operations [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation or Processing	11,282	10,404
Public Utilities, Property, Plant and Equipment, Transmission	1,726	1,305
Public Utilities, Property, Plant and Equipment, Distribution	3,197	3,059
Regulated Operation [Member] | Natural Gas Processing Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Distribution	1,565	1,507
Nonregulated Operation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(1)	(5)
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	6	10
Gross public utility property, plant and equipment in service	$ 7	$ 15
Minimum [Member] | Regulated Operation [Member] | Electric Operations [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life	20 years
Public Utilities, Property, Plant and Equipment, Transmission, Useful Life	52 years
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	20 years
Minimum [Member] | Regulated Operation [Member] | Natural Gas Processing Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	28 years
Minimum [Member] | Nonregulated Operation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	25 years
Maximum [Member] | Regulated Operation [Member] | Electric Operations [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life	70 years
Public Utilities, Property, Plant and Equipment, Transmission, Useful Life	75 years
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	75 years
Maximum [Member] | Regulated Operation [Member] | Natural Gas Processing Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	70 years
Maximum [Member] | Nonregulated Operation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	50 years
Electricity Generation Plant, Non-Nuclear [Member] | Regulated Operation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Change in Accounting Estimates, Impact on Period of Change	$ 3
Change in Accounting Estimates, Impact on Future Periods	$ 34

Property, Plant and Equipment95

Property, Plant and Equipment, Net Property, Plant and Equipment - LLC (Details) - MidAmerican Funding, LLC and Subsidiaries [Domain] - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 22	$ 22
Accumulated depreciation and amortization	9	$ 8
Construction in Progress, Gross	$ 1

Property, Plant and Equipment96

Property, Plant and Equipment, Net - NPC (Details) - Nevada Power Company [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	$ 6,883	$ 6,843
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	114	153
Public Utilities, Property, Plant and Equipment, Net	$ 6,997	$ 6,996
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	3.20%	3.00%	3.30%
Regulated Operation [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation or Processing	$ 4,271	$ 4,212
Public Utilities, Property, Plant and Equipment, Distribution	3,231	3,118
Public Utilities, Property, Plant and Equipment, Transmission	1,846	1,788
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment	738	694
Public Utilities, Property, Plant and Equipment, Plant in Service, Excluding Construction Work In Progress	10,086	9,812
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	3,205	2,971
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	6,881	6,841
Nonregulated Operation [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	$ 2	$ 2
Minimum [Member] | Regulated Operation [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life	30 years	30 years
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	20 years	20 years
Public Utilities, Property, Plant and Equipment, Transmission, Useful Life	45 years	45 years
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	5 years	5 years
Minimum [Member] | Nonregulated Operation [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	45 years	45 years
Maximum [Member] | Regulated Operation [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life	55 years	55 years
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	65 years	65 years
Public Utilities, Property, Plant and Equipment, Transmission, Useful Life	65 years	65 years
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	65 years	65 years
Maximum [Member] | Nonregulated Operation [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	45 years	45 years

Property, Plant and Equipment97

Property, Plant and Equipment, Net - SPPC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	$ 2,715	$ 2,678
Public Utilities, Property, Plant and Equipment, Net	$ 2,822	$ 2,766
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	3.00%	2.90%	3.00%
Nevada Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	$ 6,883	$ 6,843
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	114	153
Public Utilities, Property, Plant and Equipment, Net	$ 6,997	$ 6,996
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	3.20%	3.00%	3.30%
Electricity Generation Plant, Non-Nuclear [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation or Processing	$ 1,137	$ 1,134
Public Utilities, Property, Plant and Equipment, Distribution	1,417	1,382
Public Utilities, Property, Plant and Equipment, Transmission	771	739
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment	$ 164	$ 139
Electricity Generation Plant, Non-Nuclear [Member] | Minimum [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life	30 years	30 years
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	20 years	20 years
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	5 years	5 years
Public Utilities, Property, Plant and Equipment, Transmission, Useful Life	50 years	50 years
Electricity Generation Plant, Non-Nuclear [Member] | Maximum [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life	60 years	60 years
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	70 years	70 years
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	65 years	65 years
Public Utilities, Property, Plant and Equipment, Transmission, Useful Life	70 years	70 years
Natural Gas Processing Plant [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Distribution	$ 381	$ 374
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment	$ 15	$ 13
Natural Gas Processing Plant [Member] | Minimum [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	40 years	40 years
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	5 years	5 years
Natural Gas Processing Plant [Member] | Maximum [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	70 years	70 years
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	60 years	60 years
Common Facilities [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Common	$ 267	$ 265
Public Utilities, Property, Plant and Equipment, Plant in Service, Excluding Construction Work In Progress	4,152	4,046
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(1,442)	(1,368)
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	2,710	2,678
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	107	88
Public Utilities, Property, Plant and Equipment, Net	$ 2,822	$ 2,766
Common Facilities [Member] | Minimum [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Common, Useful Life	5 years	5 years
Common Facilities [Member] | Maximum [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Common, Useful Life	65 years	65 years
Nonregulated Operation [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	$ 5	$ 0
Nonregulated Operation [Member] | Nevada Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	$ 2	$ 2
Nonregulated Operation [Member] | Minimum [Member] | Nevada Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	45 years	45 years
Nonregulated Operation [Member] | Maximum [Member] | Nevada Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life	45 years	45 years
Electricity Generation Plant, Non-Nuclear [Member] | Sierra Pacific Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Change in Accounting Estimates, Impact on Future Periods		$ 9
Change in Accounting Estimate, Amount Deferred to Future Periods	$ 7

Jointly Owned Utility Facilit98

Jointly Owned Utility Facilities (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 9,730
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	4,205
Construction Work in Progress	153
PacifiCorp [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	4,336
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	1,779
Construction Work in Progress	$ 112
PacifiCorp [Member] | Jim Bridger Unit Nos 1 thru 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	67.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 1,420
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	583
Construction Work in Progress	$ 10
PacifiCorp [Member] | Hunter Unit No 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	94.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 473
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	161
Construction Work in Progress	$ 1
PacifiCorp [Member] | Hunter No. 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	60.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 296
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	98
Construction Work in Progress	$ 0
PacifiCorp [Member] | Wyodak [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	80.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 467
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	203
Construction Work in Progress	$ 1
PacifiCorp [Member] | Colstrip Unit Nos 3 and 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	10.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 244
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	130
Construction Work in Progress	$ 5
PacifiCorp [Member] | Hermiston [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 178
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	76
Construction Work in Progress	$ 2
PacifiCorp [Member] | Craig Units Nos 1 and 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	19.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 325
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	223
Construction Work in Progress	$ 32
PacifiCorp [Member] | Hayden Unit No 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	25.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 74
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	32
Construction Work in Progress	$ 0
PacifiCorp [Member] | Hayden No. 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	13.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 43
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	20
Construction Work in Progress	$ 0
PacifiCorp [Member] | Foote Creek [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	79.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 39
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	25
Construction Work in Progress	$ 0
PacifiCorp [Member] | Transmission and distribution facilities
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Percentage Share	Various
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 777
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	228
Construction Work in Progress	61
MidAmerican Energy Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	4,045
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	1,794
Construction Work in Progress	$ 35
MidAmerican Energy Company [Member] | Transmission and distribution facilities
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Percentage Share	Various
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 247
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	86
Construction Work in Progress	$ 1
MidAmerican Energy Company [Member] | Louisa Unit No 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	88.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 766
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	418
Construction Work in Progress	$ 9
MidAmerican Energy Company [Member] | Quad Cities Unit Nos 1 and 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	25.00%	[1]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 689	[1]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	367	[1]
Construction Work in Progress	$ 7	[1]
MidAmerican Energy Company [Member] | Walter Scott, Jr. No. 3 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	79.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 614
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	303
Construction Work in Progress	$ 1
MidAmerican Energy Company [Member] | Walter Scott Jr Unit No 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	60.00%	[1]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 448	[1]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	101	[1]
Construction Work in Progress	2	[1]
Revenue sharing credits netted against facility in service	319
Revenue sharing credits netted against accumulated depreciation	$ 75
MidAmerican Energy Company [Member] | George Neal No. 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	41.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 307
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	154
Construction Work in Progress	$ 1
MidAmerican Energy Company [Member] | Ottumwa Unit No 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	52.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 548
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	191
Construction Work in Progress	$ 13
MidAmerican Energy Company [Member] | George Neal Unit No 3 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	72.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 426
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	174
Construction Work in Progress	1
NV Energy [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	1,063
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	468
Construction Work in Progress	$ 6
NV Energy [Member] | Transmission and distribution facilities
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Percentage Share	Various
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 213
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	41
Construction Work in Progress	$ 0
NV Energy [Member] | Navajo Generating Station [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	11.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 213
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	145
Construction Work in Progress	$ 2
NV Energy [Member] | Silverhawk Generating Station [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	75.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 248
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	66
Construction Work in Progress	$ 3
NV Energy [Member] | Valmy [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 389
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	216
Construction Work in Progress	$ 1
BHE Pipeline Group [Member] | BHE Pipeline Group - common facilities [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Percentage Share	Various
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 286
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	164
Construction Work in Progress	$ 0
[1]	Includes amounts related to nuclear fuel.

Jointly Owned Utility Facilit99

Jointly Owned Utility Facilities - PacifiCorp (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 9,730
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	4,205
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	153
PacifiCorp [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	4,336
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	1,779
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 112
PacifiCorp [Member] | Jim Bridger Unit Nos 1 thru 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	67.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 1,420
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	583
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 10
PacifiCorp [Member] | Hunter Unit No 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	94.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 473
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	161
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1
PacifiCorp [Member] | Hunter No. 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	60.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 296
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	98
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0
PacifiCorp [Member] | Wyodak [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	80.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 467
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	203
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1
PacifiCorp [Member] | Colstrip Unit Nos 3 and 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	10.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 244
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	130
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 5
PacifiCorp [Member] | Hermiston [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 178
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	76
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 2
PacifiCorp [Member] | Craig Units Nos 1 and 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	19.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 325
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	223
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 32
PacifiCorp [Member] | Hayden Unit No 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	25.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 74
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	32
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0
PacifiCorp [Member] | Hayden No. 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	13.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 43
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	20
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0
PacifiCorp [Member] | Foote Creek [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	79.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 39
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	25
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0
PacifiCorp [Member] | Transmission and distribution facilities
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Percentage Share	Various
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 777
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	228
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 61

Jointly Owned Utility Facili100

Jointly Owned Utility Facilities Jointly Owned Utility Facilities - MEC (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 9,730
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	4,205
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	153
MidAmerican Energy Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	4,045
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	1,794
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 35
MidAmerican Energy Company [Member] | Louisa Unit No 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	88.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 766
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	418
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 9
MidAmerican Energy Company [Member] | Quad Cities Unit Nos 1 and 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	25.00%	[1]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 689	[1]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	367	[1]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 7	[1]
MidAmerican Energy Company [Member] | Walter Scott, Jr. No. 3 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	79.10%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 614
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	303
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1
MidAmerican Energy Company [Member] | Walter Scott Jr Unit No 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	59.70%	[2]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 448	[2]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	101	[2]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	2	[2]
Revenue sharing credits netted against facility in service	319
Revenue sharing credits netted against accumulated depreciation	$ 75
MidAmerican Energy Company [Member] | George Neal No. 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	40.60%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 307
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	154
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1
MidAmerican Energy Company [Member] | Ottumwa Unit No 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	52.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 548
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	191
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 13
MidAmerican Energy Company [Member] | George Neal Unit No 3 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	72.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 426
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	174
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1
MidAmerican Energy Company [Member] | Transmission facilities
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Percentage Share	Various	[3]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 247	[3]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	86	[3]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1	[3]
[1]	(1)Includes amounts related to nuclear fuel.
[2]	(2)Plant in service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling $319 million and $75 million, respectively.
[3]	(3)Includes 345 and 161 kilovolt transmission lines and substations.

Jointly Owned Utility Facili101

Jointly Owned Utility Facilities - NPC (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 9,730
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	4,205
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	153
Nevada Power Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	662
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	249
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 5
Nevada Power Company [Member] | Silverhawk Generating Station [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	75.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 248
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	66
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 3
Nevada Power Company [Member] | Navajo Generating Station [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	11.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 213
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	145
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 2
Nevada Power Company [Member] | ON Line Transmission Line [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	24.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 145
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	12
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0
Nevada Power Company [Member] | Other Transmission Facilities [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Percentage Share	Various
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 56
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	26
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0

Jointly Owned Utility Facili102

Jointly Owned Utility Facilities - SPPC (Details) $ in Millions	Dec. 31, 2016USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 9,730
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	4,205
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	153
Sierra Pacific Power Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	401
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	219
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1
Sierra Pacific Power Company [Member] | Valmy [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 389
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	216
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1
Sierra Pacific Power Company [Member] | ON Line Transmission Line [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	1.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 8
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	1
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0
Sierra Pacific Power Company [Member] | Valmy Transmission Line [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 4
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	2
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0

Regulatory Matters - Regulatory

Regulatory Matters - Regulatory Assets (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Regulatory Assets [Line Items]
Regulatory assets		$ 150	$ 130
Regulatory assets, noncurrent		4,307	4,155
Total regulatory assets		4,457	4,285
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		2,800	2,300
Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[1]	$ 1,754	1,577
Regulatory asset amortization period years	[1]	27 years
Employee benefit plans [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[2]	$ 816	778
Regulatory asset amortization period years	[2]	17 years
Asset disposition costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 281	307
Regulatory asset amortization period years		Various
Deferred net power costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 38	140
Regulatory asset amortization period years		1 year
Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 301	281
Regulatory asset amortization period years		12 years
Unrealized loss on regulated derivative contracts [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 154	250
Regulatory asset amortization period years		5 years
Abandoned Projects [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 159	136
Regulatory asset amortization period years		3 years
Unamortized contract values [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 98	110
Regulatory asset amortization period years		7 years
Regulatory assets other [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 856	$ 706
Regulatory asset amortization period years		Various
[1]	Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
[2]	Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.

Regulatory Matters - Regulat104

Regulatory Matters - Regulatory Liabilities (Details) - USD ($) $ in Millions		1 Months Ended			12 Months Ended
		Jul. 31, 2016	Oct. 31, 2015	Nov. 30, 2014	Dec. 31, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Regulatory liabilities					$ 187	$ 402
Regulatory liabilities, noncurrent					2,933	2,631
Regulatory Liabilities					3,120	3,033
Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	[1]				$ 2,242	2,167
Weighted average remaining life	[1]				27 years
Deferred net power costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities					$ 64	206
Weighted average remaining life					1 years
Asset Retirement Obligation Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities					$ 122	147
Weighted average remaining life					35 years
Levelized depreciation [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities					$ 244	199
Weighted average remaining life					23 years
Impact fees [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities					$ 90	0
Weighted average remaining life					6 years
Employee benefit plans [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	[2]				$ 25	13
Weighted average remaining life	[2]				12 years
Unrealized gain on regulated derivative contracts [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	[2]				$ 6	0
Weighted average remaining life	[2]				1 year
Regulatory liabilities other [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities					$ 327	$ 301
Weighted average remaining life					Various
Amount for discontinuance of CWIP in rate base [Member] | Alberta Utilities Commission [Member]
Regulatory Liabilities [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount			$ 82
Amount for change to flow through method for income taxes [Member] | Alberta Utilities Commission [Member]
Regulatory Liabilities [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount					$ 45
AltaLink [Member] | Alberta Utilities Commission [Member]
Regulatory Liabilities [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 415
Public Utilities, Approved Rate Increase (Decrease), Amount					200
AltaLink [Member] | 2015-2016 GTA [Member] | GTA 2015 [Member] | Alberta Utilities Commission [Member]
Regulatory Liabilities [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount		599
AltaLink [Member] | 2015-2016 GTA [Member] | GTA 2016 [Member] | Alberta Utilities Commission [Member]
Regulatory Liabilities [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount		685
AltaLink [Member] | Amount previously collected as CWIP given as refund [Member] | Alberta Utilities Commission [Member]
Regulatory Liabilities [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount		277			$ 200
AltaLink [Member] | Amount previously collected as CWIP given as returns [Member] | Alberta Utilities Commission [Member]
Regulatory Liabilities [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount		12
AltaLink [Member] | Amount for change to flow through method for income taxes [Member] | Alberta Utilities Commission [Member]
Regulatory Liabilities [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 68
2015-2016 GTA [Member] | AltaLink [Member] | GTA 2015 [Member] | Alberta Utilities Commission [Member]
Regulatory Liabilities [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount			672	$ 811
2015-2016 GTA [Member] | AltaLink [Member] | GTA 2016 [Member] | Alberta Utilities Commission [Member]
Regulatory Liabilities [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount			$ 704	$ 1,000
[1]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
[2]	Represents amounts not yet recognized as a component of net periodic benefit cost that are to be returned to customers in future periods when recognized.ALP General Tariff Application ("GTA")In November 2014, ALP filed a GTA requesting the Alberta Utilities Commission ("AUC") to approve revenue requirements of C$811 million for 2015 and C$1.0 billion for 2016, primarily due to continued investment in capital projects as directed by the Alberta Electric System Operator. ALP amended the GTA in June 2015 to propose transmission tariff relief measures for customers and modifications to its capital structure. ALP also amended and updated the GTA in October 2015, reducing the requested revenue requirements to C$672 million for 2015 and C$704 million for 2016. In May 2016, the AUC issued its decision pertaining to the 2015-2016 GTA. ALP filed its 2015-2016 GTA compliance filing in July 2016 to comply with the AUC's decision.The compliance filing requested the AUC to approve revenue requirements of C$599 million for 2015 and C$685 million for 2016. The decreased revenue requirements requested in the compliance filing, as compared to the 2015-2016 GTA filing updated in October 2015, were primarily due to the AUC approval of ALP's proposed immediate tariff relief of C$415 million for customers for 2015 and 2016, through (i) the discontinuance of construction work-in-progress ("CWIP") in rate base and the return to allowance for funds used during construction ("AFUDC") accounting effective January 1, 2015, resulting in a C$82 million reduction of revenue requirement and the refund of C$277 million previously collected as CWIP in rate base as part of ALP's transmission tariffs during 2011-2014 less related returns of C$12 million and (ii) a change to the flow through method for calculating income taxes for 2016, resulting in further tariff relief of C$68 million.Operating revenue for the year ended December 31, 2016, included a one-time reduction of $200 million from the 2015-2016 GTA decision received in May 2016 at ALP. The 2015-2016 GTA decision required ALP to refund $200 million to customers in 2016 through reduced monthly billings for the change from receiving cash during construction for the return on CWIP in rate base to recording allowance for borrowed and equity funds used during construction related to construction expenditures during the 2011 to 2014 time period. This amount is offset with higher capitalized interest and allowance for equity funds in the Consolidated Statements of Operations. In addition, the decision required ALP to change to the flow through method of recognizing income tax expense effective January 1, 2016. This change reduced operating revenue by $45 million for the year ended December 31, 2016, with offsetting impacts to income tax expense in the Consolidated Statements of Operations.

Regulatory Matters - PacifiCorp

Regulatory Matters - PacifiCorp - Regulatory Assets (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Regulatory Assets [Line Items]
Regulatory assets		$ 150	$ 130
Regulatory assets, noncurrent		4,307	4,155
Total regulatory assets		4,457	4,285
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		2,800	2,300
Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[1]	$ 1,754	1,577
Regulatory asset amortization period years	[1]	27 years
Employee benefit plans [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[2]	$ 816	778
Regulatory asset amortization period years	[2]	17 years
Unamortized contract values [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 98	110
Regulatory asset amortization period years		7 years
Deferred net power costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 38	140
Regulatory asset amortization period years		1 year
Unrealized loss on regulated derivative contracts [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 154	250
Regulatory asset amortization period years		5 years
Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 301	281
Regulatory asset amortization period years		12 years
PacifiCorp [Member]
Regulatory Assets [Line Items]
Regulatory assets		$ 53	102
Regulatory assets, noncurrent		1,490	1,583
Total regulatory assets		1,543	1,685
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		1,019	1,102
PacifiCorp [Member] | Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[3]	$ 421	437
Regulatory asset amortization period years	[3]	26 years
PacifiCorp [Member] | Employee benefit plans [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[4]	$ 525	499
Regulatory asset amortization period years	[4]	21 years
PacifiCorp [Member] | Utah mine disposition [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[5]	$ 166	186
Regulatory asset amortization period years	[5]	Various
PacifiCorp [Member] | Unamortized contract values [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 98	110
Regulatory asset amortization period years		7 years
PacifiCorp [Member] | Deferred net power costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 33	86
Regulatory asset amortization period years		1 year
PacifiCorp [Member] | Unrealized loss on regulated derivative contracts [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 73	133
Regulatory asset amortization period years		5 years
PacifiCorp [Member] | Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 82	65
Regulatory asset amortization period years		20 years
PacifiCorp [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 145	$ 169
Regulatory asset amortization period years		Various
[1]	Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
[2]	Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.
[3]	(1)Amounts primarily represent income tax benefits and expense related to certain property-related basis differences and other various items that PacifiCorp is required to pass on to its customers.
[4]	(2)Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in rates when recognized.
[5]	(3)Amounts represent regulatory assets established as a result of the Utah mine disposition discussed below for the net property, plant and equipment not considered probable of disallowance and for the portion of losses associated with the assets held for sale, UMWA 1974 Pension Plan withdrawal and closure costs incurred to date considered probable of recovery.

Regulatory Matters - PacifiC106

Regulatory Matters - PacifiCorp - Regulatory Liabilities (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Regulatory liabilities		$ 187	$ 402
Regulatory liabilities, noncurrent		2,933	2,631
Regulatory Liabilities		3,120	3,033
Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	[1]	$ 2,242	2,167
Regulatory liability amortization period years	[1]	27 years
PacifiCorp [Member]
Regulatory Liabilities [Line Items]
Regulatory liabilities		$ 54	34
Regulatory liabilities, noncurrent		978	938
Regulatory Liabilities		1,032	972
PacifiCorp [Member] | Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liabilities, noncurrent		917	894
Regulatory Liabilities	[2]	$ 917	894
Regulatory liability amortization period years	[2]	26 years
PacifiCorp [Member] | Deferred Income Tax Charge [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 9	12
Regulatory liability amortization period years		Various
PacifiCorp [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 106	$ 66
Regulatory liability amortization period years		Various
[1]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
[2]	(1)Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.

Regulatory Matters - MEC - Regu

Regulatory Matters - MEC - Regulatory Assets (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Regulatory Assets [Line Items]
Regulatory assets		$ 4,307	$ 4,155
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		$ 2,800	2,300
Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[1]	27 years
Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		12 years
Employee benefit plans [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[2]	17 years
Unrealized loss on regulated derivative contracts [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		5 years
MidAmerican Energy Company [Member]
Regulatory Assets [Line Items]
Regulatory assets		$ 1,161	1,044
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		$ 1,200	1,000
MidAmerican Energy Company [Member] | Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period	[3]	29 years
Regulatory assets	[3]	$ 985	858
MidAmerican Energy Company [Member] | Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period	[4]	9 years
Regulatory assets	[4]	$ 105	94
MidAmerican Energy Company [Member] | Employee benefit plans [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period	[5]	11 years
Regulatory assets	[5]	$ 40	39
MidAmerican Energy Company [Member] | Unrealized loss on regulated derivative contracts [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		1 year
Regulatory assets		$ 2	20
MidAmerican Energy Company [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		Various
Regulatory assets		$ 29	$ 33
[1]	Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
[2]	Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.
[3]	(1)Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
[4]	(2)Amount predominantly relates to asset retirement obligations for fossil-fueled and wind-powered generating facilities. Refer to Note 12 for a discussion of asset retirement obligations.
[5]	(3)Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.

Regulatory Matters - MEC - R108

Regulatory Matters - MEC - Regulatory Liabilities (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Regulatory liabilities		$ 2,933	$ 2,631
Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[1]	27 years
Asset Retirement Obligation Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		35 years
Pension and other postretirement costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[2]	12 years
Unrealized gain on regulated derivative contracts [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[2]	1 year
MidAmerican Energy Company [Member]
Regulatory Liabilities [Line Items]
Regulatory liabilities		$ 883	831
MidAmerican Energy Company [Member] | Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[3]	29 years
Regulatory liabilities	[3]	$ 665	653
MidAmerican Energy Company [Member] | Asset Retirement Obligation Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[4]	36 years
Regulatory liabilities	[4]	$ 117	140
MidAmerican Energy Company [Member] | Transmission MVP CWIP Return [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[5]	56 years
Regulatory liabilities	[5]	$ 35	19
MidAmerican Energy Company [Member] | Regulatory revenue sharing arrangement [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[6]	1 year
Regulatory liabilities	[6]	$ 30	0
MidAmerican Energy Company [Member] | Pension and other postretirement costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[7]	11 years
Regulatory liabilities	[7]	$ 12	0
MidAmerican Energy Company [Member] | Unrealized gain on regulated derivative contracts [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		1 year
Regulatory liabilities		$ 6	0
MidAmerican Energy Company [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		Various
Regulatory liabilities		$ 18	$ 19
[1]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
[2]	Represents amounts not yet recognized as a component of net periodic benefit cost that are to be returned to customers in future periods when recognized.ALP General Tariff Application ("GTA")In November 2014, ALP filed a GTA requesting the Alberta Utilities Commission ("AUC") to approve revenue requirements of C$811 million for 2015 and C$1.0 billion for 2016, primarily due to continued investment in capital projects as directed by the Alberta Electric System Operator. ALP amended the GTA in June 2015 to propose transmission tariff relief measures for customers and modifications to its capital structure. ALP also amended and updated the GTA in October 2015, reducing the requested revenue requirements to C$672 million for 2015 and C$704 million for 2016. In May 2016, the AUC issued its decision pertaining to the 2015-2016 GTA. ALP filed its 2015-2016 GTA compliance filing in July 2016 to comply with the AUC's decision.The compliance filing requested the AUC to approve revenue requirements of C$599 million for 2015 and C$685 million for 2016. The decreased revenue requirements requested in the compliance filing, as compared to the 2015-2016 GTA filing updated in October 2015, were primarily due to the AUC approval of ALP's proposed immediate tariff relief of C$415 million for customers for 2015 and 2016, through (i) the discontinuance of construction work-in-progress ("CWIP") in rate base and the return to allowance for funds used during construction ("AFUDC") accounting effective January 1, 2015, resulting in a C$82 million reduction of revenue requirement and the refund of C$277 million previously collected as CWIP in rate base as part of ALP's transmission tariffs during 2011-2014 less related returns of C$12 million and (ii) a change to the flow through method for calculating income taxes for 2016, resulting in further tariff relief of C$68 million.Operating revenue for the year ended December 31, 2016, included a one-time reduction of $200 million from the 2015-2016 GTA decision received in May 2016 at ALP. The 2015-2016 GTA decision required ALP to refund $200 million to customers in 2016 through reduced monthly billings for the change from receiving cash during construction for the return on CWIP in rate base to recording allowance for borrowed and equity funds used during construction related to construction expenditures during the 2011 to 2014 time period. This amount is offset with higher capitalized interest and allowance for equity funds in the Consolidated Statements of Operations. In addition, the decision required ALP to change to the flow through method of recognizing income tax expense effective January 1, 2016. This change reduced operating revenue by $45 million for the year ended December 31, 2016, with offsetting impacts to income tax expense in the Consolidated Statements of Operations.
[3]	(1)Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing utility plant in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
[4]	(2)Amount predominantly represents the excess of nuclear decommission trust assets over the related asset retirement obligation. Refer to Note 12 for a discussion of asset retirement obligations.
[5]	(3)Represents AFUDC accrued on transmission MVPs that is deducted from rate base as a result of the inclusion of related construction work-in-progress in rate base.
[6]	(4)Represents current-year accruals under a regulatory arrangement in Iowa in which equity returns exceeding specified thresholds reduce utility plant upon final determination.
[7]	(5)Represents amounts not yet recognized as a component of net periodic benefit cost that are to be returned to customers in future periods when recognized.

Regulatory Matters Regulatory M

Regulatory Matters Regulatory Matters - NPC - Regulatory Assets (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Regulatory Assets [Line Items]
Total regulatory assets		$ 4,457	$ 4,285
Regulatory assets		150	130
Regulatory assets		4,307	4,155
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		$ 2,800	2,300
Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[1]	27 years
Total regulatory assets	[1]	$ 1,754	1,577
Employee benefit plans [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[2]	17 years
Total regulatory assets	[2]	$ 816	778
Abandoned Projects [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		3 years
Total regulatory assets		$ 159	136
Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		12 years
Total regulatory assets		$ 301	281
Regulatory assets other [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		Various
Total regulatory assets		$ 856	706
Nevada Power Company [Member]
Regulatory Assets [Line Items]
Total regulatory assets		1,020	1,057
Regulatory assets		20	0
Regulatory assets		1,000	1,057
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		$ 560	572
Nevada Power Company [Member] | Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[3]	P27Y
Total regulatory assets	[3]	$ 141	149
Nevada Power Company [Member] | Acquisition-related Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P28Y
Total regulatory assets		$ 136	143
Nevada Power Company [Member] | Deferred Operating Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P20Y
Total regulatory assets		$ 127	87
Nevada Power Company [Member] | Decommissioning costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P7Y
Total regulatory assets		$ 114	121
Nevada Power Company [Member] | Employee benefit plans [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[4]	P10Y
Nevada Power Company [Member] | Pension and Other Postretirement Plans Costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[4]	$ 105	98
Nevada Power Company [Member] | Abandoned Projects [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P3Y
Total regulatory assets		$ 75	91
Nevada Power Company [Member] | Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P7Y
Total regulatory assets		$ 74	79
Nevada Power Company [Member] | Legacy Meters [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P16Y
Total regulatory assets		$ 60	64
Nevada Power Company [Member] | Deferred Excess Energy Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P3Y
Total regulatory assets		$ 40	56
Nevada Power Company [Member] | Regulatory assets other [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		Various
Nevada Power Company [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 148	$ 169
[1]	Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
[2]	Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.
[3]	Amounts represent income tax benefits related to accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
[4]	(2)Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.

Regulatory Matters - NPC - Regu

Regulatory Matters - NPC - Regulatory Liabilities (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 3,120	$ 3,033
Regulatory liabilities		187	402
Regulatory liabilities		$ 2,933	2,631
Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[1]	27 years
Regulatory Liabilities	[1]	$ 2,242	2,167
Impact fees [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		6 years
Regulatory Liabilities		$ 90	0
Regulatory liabilities other [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		Various
Regulatory Liabilities		$ 327	301
Nevada Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		453	477
Regulatory liabilities		37	173
Regulatory liabilities		$ 416	304
Nevada Power Company [Member] | Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[2]	P33Y
Regulatory Liabilities	[2]	$ 294	273
Nevada Power Company [Member] | Impact fees [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		P6Y
Regulatory Liabilities		$ 90	0
Nevada Power Company [Member] | Energy Efficiency Program [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		P1Y
Regulatory Liabilities		$ 37	34
Nevada Power Company [Member] | Deferred Excess Energy Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		P1Y
Regulatory Liabilities		$ 0	139
Nevada Power Company [Member] | Regulatory liabilities other [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		Various
Regulatory Liabilities		$ 32	$ 31
[1]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
[2]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.

Regulatory Matters - NPC - Othe

Regulatory Matters - NPC - Other (Details) - Nevada Power Company [Member] - Public Utilities Commission, Nevada [Member] - USD ($) $ in Millions	1 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Dec. 31, 2015
Public Utilities, General Disclosures [Line Items]
Total impact fee		$ 97
Regulatory Liabilities	$ 2
Energy Efficiency Rate Case [Member]
Public Utilities, General Disclosures [Line Items]
Customer Refund Liability, Current	$ 10		$ 18

Regulatory Matters - SPPC - Reg

Regulatory Matters - SPPC - Regulatory Assets (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Regulatory Assets [Line Items]
Total regulatory assets		$ 4,457	$ 4,285
Regulatory assets		150	130
Regulatory assets		4,307	4,155
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		2,800	2,300
Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[1]	1,754	1,577
Abandoned Projects [Member]
Regulatory Assets [Line Items]
Total regulatory assets		159	136
Sierra Pacific Power Company [Member]
Regulatory Assets [Line Items]
Total regulatory assets		435	432
Regulatory assets		25	0
Regulatory assets		410	432
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		$ 305	254
Sierra Pacific Power Company [Member] | Pension and Other Postretirement Plans Costs [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period	[2]	10 years
Total regulatory assets	[2]	$ 128	126
Sierra Pacific Power Company [Member] | Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period	[3]	27 years
Total regulatory assets	[3]	$ 85	90
Sierra Pacific Power Company [Member] | Acquisition-related Costs [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		30 years
Total regulatory assets		$ 80	83
Sierra Pacific Power Company [Member] | Abandoned Projects [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		9 years
Total regulatory assets		$ 39	44
Sierra Pacific Power Company [Member] | Renewable Energy Program [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		1 year
Total regulatory assets		$ 25	0
Sierra Pacific Power Company [Member] | Loss on Reacquired Debt [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		17 years
Total regulatory assets		$ 22	22
Sierra Pacific Power Company [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 56	$ 67
[1]	Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
[2]	Amounts represent income tax benefits related to accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse
[3]	Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.

Regulatory Matters - SPPC - 113

Regulatory Matters - SPPC - Regulatory Liabilities - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 3,120	$ 3,033
Regulatory liabilities		187	402
Regulatory liabilities		2,933	2,631
Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	[1]	2,242	2,167
Regulatory liabilities other [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		327	301
Sierra Pacific Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		290	308
Regulatory liabilities		69	78
Regulatory liabilities		$ 221	230
Sierra Pacific Power Company [Member] | Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		39 years
Regulatory Liabilities	[2]	$ 205	208
Sierra Pacific Power Company [Member] | Deferred Excess Energy Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		1 year
Regulatory Liabilities		$ 64	66
Sierra Pacific Power Company [Member] | Renewable Energy Program [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		1 year
Regulatory Liabilities		$ 0	8
Sierra Pacific Power Company [Member] | Regulatory liabilities other [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 21	$ 26
[1]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
[2]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.

Regulatory Matters - SPPC - Oth

Regulatory Matters - SPPC - Other (Details) - Sierra Pacific Power Company [Member] - Public Utilities Commission, Nevada [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Energy Efficiency Rate Case [Member]
Public Utilities, General Disclosures [Line Items]
Customer Refund Liability, Current	$ 2	$ 3
Electric Distribution [Member] | General Rate Case [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount	3
Gas Distribution [Member] | General Rate Case [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 2

Investments and Restricted C115

Investments and Restricted Cash and Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Investments [Abstract]
Investments	$ 1,694	$ 1,748
Equity Method Investments [Abstract]
Equity method investments	1,720	1,103
Restricted Cash and Investments [Abstract]
Restricted cash and investments	742	653
Investments, including equity method and restricted cash and investments, current	211	137
Investments, including equity method and restricted cash and investments, noncurrent	3,945	3,367
Investments, including equity method and restricted cash and investments	4,156	3,504
Quad Cities Station nuclear decommissioning trust funds [Member]
Restricted Cash and Investments [Abstract]
Decommissioning Fund Investments, Fair Value	460	429
Solar Star and Topaz Projects [Member]
Restricted Cash and Investments [Abstract]
Restricted cash and investments	64	95
Restricted Cash and Investments, Other [Member]
Restricted Cash and Investments [Abstract]
Restricted cash and investments	218	129
Electric Transmission Texas, LLC [Member]
Equity Method Investments [Abstract]
Equity method investments	$ 672	585
Equity method investment, ownership percentage	50.00%
Bridger Coal Company [Member]
Equity Method Investments [Abstract]
Equity method investments	$ 165	190
Equity method investment, ownership percentage	66.67%
Tax Equity Investments
Equity Method Investments [Abstract]
Equity method investments	$ 741	168
Other equity method investments [Member]
Equity Method Investments [Abstract]
Equity method investments	142	160
BYD Company Limited common stock [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Available-for-sale Securities, Change in Net Unrealized Holding Gain (Loss) before Taxes	953	1,006
Investments [Abstract]
Available-for-sale Securities, Equity Securities	1,185	1,238
Rabbi trusts [Member]
Investments [Abstract]
Life Insurance, Corporate or Bank Owned, Amount	403	380
Other investments [Member]
Investments [Abstract]
Other Investments	$ 106	$ 130

Investments and Restricted C116

Investments and Restricted Cash and Investments Investments and Restricted Cash and Investments - MEC - (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Investments and restricted cash and investments	$ 3,945	$ 3,367
MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Decommissioning Fund Investments, Fair Value	460	429
Life Insurance, Corporate or Bank Owned, Amount	184	175
Available-for-sale Securities, Equity Securities	0	26
Other Investments	9	4
Investments and restricted cash and investments	$ 653	$ 634
MidAmerican Energy Company [Member] | Domestic Equity Securities [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Nuclear Decommissioning Trust Fund Ownership Percentage	54.00%	56.00%
MidAmerican Energy Company [Member] | US Government Corporations and Agencies Securities [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Nuclear Decommissioning Trust Fund Ownership Percentage	35.00%	31.00%
MidAmerican Energy Company [Member] | Domestic Corporate Debt Securities [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Nuclear Decommissioning Trust Fund Ownership Percentage	8.00%	9.00%
MidAmerican Energy Company [Member] | Other Securities [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Nuclear Decommissioning Trust Fund Ownership Percentage	3.00%	4.00%
MidAmerican Energy Company [Member] | Auction Rate Securities [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Available-for-sale Debt Securities, Amortized Cost Basis		$ 35
Other than Temporary Impairment Losses, Investments, Portion Recognized in Earnings, Net, Available-for-sale Securities	$ 3
Accumulated Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax		$ 3
Available-for-sale securities, realized gains, net of tax	$ 3

Investments and Restricted C117

Investments and Restricted Cash and Investments - MidAmerican Funding - (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
MidAmerican Funding, LLC and Subsidiaries [Domain]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Life Insurance, Corporate or Bank Owned, Amount	$ 2	$ 2

Short-Term Debt and Credit F118

Short-Term Debt and Credit Facilities Short-Term Debt and Credit Facilities - Credit Facilities (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,345	$ 6,421
Short-term debt	[1]	1,869	974
Line of Credit Facility, Amounts Supported	[1]	457	415
Line of Credit Facility, Remaining Borrowing Capacity	[1]	4,019	5,032
Berkshire Hathaway Energy [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		2,000	2,000
Short-term debt		834	253
Line of Credit Facility, Amounts Supported		7	51
Line of Credit Facility, Remaining Borrowing Capacity		1,159	1,696
PacifiCorp [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		1,000	1,200
Short-term debt		270	20
Line of Credit Facility, Amounts Supported		142	160
Line of Credit Facility, Remaining Borrowing Capacity		588	1,020
MidAmerican Funding [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		609	609
Short-term debt		99	0
Line of Credit Facility, Amounts Supported		220	195
Line of Credit Facility, Remaining Borrowing Capacity		290	414
NV Energy [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		650	650
Short-term debt		0	0
Line of Credit Facility, Amounts Supported		80	0
Line of Credit Facility, Remaining Borrowing Capacity		570	650
Northern Powergrid Holdings [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		185	221
Short-term debt		0	0
Line of Credit Facility, Amounts Supported		0	0
Line of Credit Facility, Remaining Borrowing Capacity		185	221
AltaLink [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		986	813
Short-term debt		289	401
Line of Credit Facility, Amounts Supported		8	9
Line of Credit Facility, Remaining Borrowing Capacity		689	403
Other [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		915	928
Short-term debt		377	300
Line of Credit Facility, Amounts Supported		0	0
Line of Credit Facility, Remaining Borrowing Capacity		$ 538	$ 628
[1]	The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.

Short-Term Debt and Credit F119

Short-Term Debt and Credit Faciliites (Details) £ in Millions, CAD in Millions, $ in Millions		Dec. 31, 2016USD ($)	Dec. 31, 2016CAD	Dec. 31, 2016GBP (£)	Dec. 31, 2015USD ($)	Feb. 29, 2012USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,345			$ 6,421
Line of Credit Facility, Amounts Supported	[1]	(457)			(415)
Short-term Debt	[1]	(1,869)			(974)
Berkshire Hathaway Energy [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		2,000			2,000
Letters of Credit Outstanding, Amount		123			142
Line of Credit Facility, Amounts Supported		(7)			(51)
Short-term Debt		$ (834)			$ (253)
Berkshire Hathaway Energy [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.88%	0.88%	0.88%	0.66%
Debt to capitalization ratio		0.70	0.70	0.70
Berkshire Hathaway Energy [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Amounts Supported		$ (7)			$ (51)
PacifiCorp [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		1,000			1,200
Letters of Credit Outstanding, Amount		255			310
Line of Credit Facility, Amounts Supported		(142)			(160)
Short-term Debt		$ (270)			$ (20)
PacifiCorp [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.96%	0.96%	0.96%	0.65%
Debt to capitalization ratio		0.65	0.65	0.65
PacifiCorp [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Amounts Supported					$ (10)
MidAmerican Funding [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 609			609
Line of Credit Facility, Amounts Supported		(220)			(195)
Short-term Debt		$ (99)			0
MidAmerican Funding [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.73%	0.73%	0.73%
Debt to capitalization ratio		0.65	0.65	0.65
Sierra Pacific Power Company [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 250			250
Line of Credit Facility, Amounts Supported		(80)			0
Northern Powergrid Holdings [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		185			221
Line of Credit Facility, Amounts Supported		0			0
Short-term Debt		0			0
AltaLink, L.P. [Member]
Line of Credit Facility [Line Items]
Short-term Debt		$ (26)			$ (324)
AltaLink, L.P. [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.99%	0.99%	0.99%	0.94%
Debt to capitalization ratio		0.75	0.75	0.75
ALP Investments [Member]
Line of Credit Facility [Line Items]
Short-term Debt		$ (263)			$ (77)
ALP Investments [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		1.74%	1.74%	1.74%	2.09%
Debt to capitalization ratio		0.8	0.8	0.8
EBITDA to interest expense ratio		2.25	2.25	2.25
ALP Investments [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity | CAD			CAD 10
HomeServices [Member]
Line of Credit Facility [Line Items]
Short-term Debt					$ (50)
BHE Renewables [Member]
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount		$ 106			$ 65
Unsecured credit facility, $2 billion, expiring June 2019 [Member] | Berkshire Hathaway Energy [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 2,000
Unsecured credit facility, £150 million, expiring August 2017 [Member] | Northern Powergrid (Yorkshire) plc [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt to regulated asset value		0.65	0.65	0.65
Unsecured credit facility, $600 million, expiring March 2018 [Member] | PacifiCorp [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 600
Unsecured credit facility, $600 million, expiring March 2018 [Member] | MidAmerican Funding [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		600
Unsecured credit facility, $400 million, expiring June 2019 [Member] | PacifiCorp [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		400
Secured credit facility, $400 million, expiring March 2018 [Member] | Nevada Power Company [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 400
Debt to capitalization ratio		0.68	0.68	0.68
Secured credit facility, $250 million, expiring March 2018 [Member] | Sierra Pacific Power Company [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 250
Debt to capitalization ratio		0.68	0.68	0.68
Unsecured credit facility, £150 million, expiring August 2020 [Member] | Northern Powergrid Holdings [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity | £				£ 150
Debt to regulated asset value		0.8	0.8	0.8
Interest coverage ratio		2.5	2.5	2.5
Unsecured credit facility, £150 million, expiring August 2020 [Member] | Northern Powergrid (Northeast) Limited [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt to regulated asset value		0.65	0.65	0.65
Secured credit facility, C$750 million, expiring December 2017 [Member] | AltaLink, L.P. [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity | CAD			CAD 750
Secured credit facility, C$75 million, expiring December 2017 [Member] | AltaLink, L.P. [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity | CAD			75
Secured credit facility, C$300 million, expiring December 2020 | ALP Investments [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity | CAD			CAD 300
Unsecured credit facility, $350 million, expiring July 2018 [Member] | HomeServices [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 350
Debt, Weighted Average Interest Rate					1.77%
Unsecured credit facility, $578 million, expiring February 2016 through December 2016 [Member] | HomeServices [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 565
Debt, Weighted Average Interest Rate		2.77%	2.77%	2.77%
Short-term Debt		$ (327)
Unsecured credit facility, $503 million, expiring May 2015 through December 2015 [Member] | HomeServices [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity					$ 578
Debt, Weighted Average Interest Rate					2.42%
Short-term Debt					$ (300)
Letter of credit and reimbursement facility, Topaz and Solar Star [Member] | BHE Renewables [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity						$ 627
Letters of Credit Outstanding, Amount		$ 599			$ 600
[1]	The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.

Short-Term Debt and Credit F120

Short-Term Debt and Credit Facilities - PacifiCorp - Credit Facility (Details) $ in Millions		Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,345	$ 6,421
Short-term Debt	[1]	(1,869)	(974)
Line of Credit Facility, Amounts Supported	[1]	(457)	(415)
Line of Credit Facility, Remaining Borrowing Capacity	[1]	4,019	5,032
PacifiCorp [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		1,000	1,200
Short-term Debt		(270)	(20)
Line of Credit Facility, Amounts Supported		(142)	(160)
Line of Credit Facility, Remaining Borrowing Capacity		588	1,020
Letters of Credit Outstanding, Amount		$ 255	$ 310
PacifiCorp [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.96%	0.65%
Debt to capitalization ratio		0.65
PacifiCorp [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.96%	0.65%
PacifiCorp [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Amounts Supported			$ (10)
PacifiCorp [Member] | Unsecured credit facility, $600 million, expiring June 2017 [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 600
PacifiCorp [Member] | Unsecured credit facility, $600 million, expiring March 2018 [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		400
PacifiCorp [Member] | Certain transactions required by third parties [Member]
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount		14
PacifiCorp [Member] | Tax exempt bond obligations and commodity contract collateral requirement [Member]
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount		$ 255	$ 310
[1]	The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.

Short-Term Debt and Credit F121

Short-Term Debt and Credit Facilities - MEC - Credit Facility (Details) $ in Millions		Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,345	$ 6,421
Short-term Debt	[1]	(1,869)	(974)
Line of Credit Facility, Amounts Supported	[1]	(457)	(415)
Line of Credit Facility, Remaining Borrowing Capacity	[1]	4,019	5,032
MidAmerican Energy Company [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		605	605
Short-term Debt		(99)	0
Line of Credit Facility, Amounts Supported		(220)	(195)
Line of Credit Facility, Remaining Borrowing Capacity		$ 286	$ 410
MidAmerican Energy Company [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt to capitalization ratio		0.65
MidAmerican Energy Company [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Short-term Debt, Weighted Average Interest Rate		0.73%
Regulatory Approval for Additional Short-Term Debt Issuances		$ 605
MidAmerican Energy Company [Member] | Unsecured credit facility, $600 million, expiring March 2018 [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		600
MidAmerican Energy Company [Member] | Unsecured 364-day Credit Facility, $5 million, expiring June [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 5
[1]	The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.

Short-Term Debt and Credit F122

Short-Term Debt and Credit Facilities - MidAmerican Funding (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,345	$ 6,421
MidAmerican Funding, LLC and Subsidiaries [Domain] | Unsecured 364-day credit facility, $4 million, expiring June [Member] | MHC, Inc. [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 4
Line of Credit Facility, Expiration Date		Jun. 30, 2017
Outstanding balance on credit facility		$ 0	$ 0
[1]	The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.

Short-Term Debt and Credit F123

Short-Term Debt and Credit Facilities - NPC - Credit Facility (Details)		Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,345,000,000	$ 6,421,000,000
Nevada Power Company [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		400,000,000
Long-term Line of Credit		0	0
Nevada Power Company [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Long-term Line of Credit		$ 0	$ 0
Nevada Power Company [Member] | Senior unsecured credit facility, $400 million, expiring March 2018 [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt to capitalization ratio		0.68	0.68
[1]	The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.

Short-Term Debt and Credit F124

Short-Term Debt and Credit Facilities - SPPC - Credit Facility (Details) $ in Millions		Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,345	$ 6,421
Line of Credit Facility, Amounts Supported	[1]	(457)	(415)
Line of Credit Facility, Remaining Borrowing Capacity	[1]	4,019	5,032
Sierra Pacific Power Company [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		250	250
Line of Credit Facility, Amounts Supported		(80)	0
Line of Credit Facility, Remaining Borrowing Capacity		170	$ 250
Sierra Pacific Power Company [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 250
Debt to capitalization ratio		0.68	0.68
[1]	The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.

BHE Debt (Details)

BHE Debt (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Feb. 28, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
BHE Debt [Line Items]
Par value		$ 36,295
Noncurrent senior debt		7,418	$ 7,814
BHE junior subordinated debentures		944	2,944
Interest expense to Berkshire Hathaway		65	104	$ 78
Senior Notes [Member] | Berkshire Hathaway Energy [Member]
BHE Debt [Line Items]
Par value		7,875
Total BHE Senior Debt		7,818	7,814
Current senior debt		400	0
Noncurrent senior debt		7,418	7,814
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 1.10%, Senior Notes, due 2017 [Member]
BHE Debt [Line Items]
Par value		400
Total BHE Senior Debt		$ 400	$ 399
Debt Instrument, Interest Rate, Stated Percentage		1.10%	1.10%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 5.75%, Senior Notes, due 2018 [Member]
BHE Debt [Line Items]
Par value		$ 650
Total BHE Senior Debt		$ 649	$ 648
Debt Instrument, Interest Rate, Stated Percentage		5.75%	5.75%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 2.00%, Senior Notes, due 2018 [Member]
BHE Debt [Line Items]
Par value		$ 350
Total BHE Senior Debt		$ 349	$ 348
Debt Instrument, Interest Rate, Stated Percentage		2.00%	2.00%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 2.40% Senior Notes, due 2020 [Member]
BHE Debt [Line Items]
Par value		$ 350
Total BHE Senior Debt		$ 349	$ 348
Debt Instrument, Interest Rate, Stated Percentage		2.40%	2.40%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 3.75%, Senior Notes, due 2023 [Member]
BHE Debt [Line Items]
Par value		$ 500
Total BHE Senior Debt		$ 497	$ 497
Debt Instrument, Interest Rate, Stated Percentage		3.75%	3.75%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 3.50% Senior Notes, due 2025 [Member]
BHE Debt [Line Items]
Par value		$ 400
Total BHE Senior Debt		$ 397	$ 397
Debt Instrument, Interest Rate, Stated Percentage		3.50%	3.50%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 8.48%, Senior Notes, due 2028 [Member]
BHE Debt [Line Items]
Par value		$ 475
Total BHE Senior Debt		$ 477	$ 477
Debt Instrument, Interest Rate, Stated Percentage		8.48%	8.48%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 6.125%, Senior Bonds, due 2036 [Member]
BHE Debt [Line Items]
Par value		$ 1,700
Total BHE Senior Debt		$ 1,690	$ 1,690
Debt Instrument, Interest Rate, Stated Percentage		6.125%	6.125%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 5.95%, Senior Bonds, due 2037 [Member]
BHE Debt [Line Items]
Par value		$ 550
Total BHE Senior Debt		$ 547	$ 547
Debt Instrument, Interest Rate, Stated Percentage		5.95%	5.95%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 6.50%, Senior Bonds, due 2037 [Member]
BHE Debt [Line Items]
Par value		$ 1,000
Total BHE Senior Debt		$ 987	$ 987
Debt Instrument, Interest Rate, Stated Percentage		6.50%	6.50%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 5.15%, Senior Notes, due 2043 [Member]
BHE Debt [Line Items]
Par value		$ 750
Total BHE Senior Debt		$ 739	$ 739
Debt Instrument, Interest Rate, Stated Percentage		5.15%	5.15%
Senior Notes [Member] | Berkshire Hathaway Energy [Member] | 4.50% Senior Notes, due 2045 [Member]
BHE Debt [Line Items]
Par value		$ 750
Total BHE Senior Debt		$ 737	$ 737
Debt Instrument, Interest Rate, Stated Percentage		4.50%	4.50%
Junior Subordinated Debt [Member] | Berkshire Hathaway Energy [Member]
BHE Debt [Line Items]
Par value		$ 944
BHE junior subordinated debentures		$ 944	$ 2,944
BHE junior subordinated debentures Maturity Period		30 years
Long-Term Debt, Variable Interest Rate, Base Rate Floor		1.00%
Base Rate, Principal Repayment Trigger		50.00%
Junior Subordinated Debt [Member] | Berkshire Hathaway Energy [Member] | BHE Junior Subordinated Debentures, due 2043 [Member]
BHE Debt [Line Items]
Par value		$ 0
BHE junior subordinated debentures		$ 0	1,444
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		3.00%
Junior Subordinated Debt [Member] | Berkshire Hathaway Energy [Member] | BHE Junior Subordinated Debentures, due 2044 [Member]
BHE Debt [Line Items]
Par value		$ 944
BHE junior subordinated debentures		$ 944	$ 1,500
Basis Point Spread, Up To 3rd Anniversary Date [Member] | Junior Subordinated Debt [Member] | Berkshire Hathaway Energy [Member] | BHE Junior Subordinated Debentures, due 2043 [Member]
BHE Debt [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		2.00%
Basis Point Spread, 3rd Anniversary up to 7th Anniversary Date [Member] | Junior Subordinated Debt [Member] | Berkshire Hathaway Energy [Member] | BHE Junior Subordinated Debentures, due 2043 [Member]
BHE Debt [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		3.00%
Basis Point Spread, If 50% of principal is paid by 3rd Anniversary Date [Member] | Junior Subordinated Debt [Member] | Berkshire Hathaway Energy [Member] | BHE Junior Subordinated Debentures, due 2043 [Member]
BHE Debt [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		2.00%
Basis Point Spread, 7th Anniversary Date Until Maturity Date [Member] | Junior Subordinated Debt [Member] | Berkshire Hathaway Energy [Member] | BHE Junior Subordinated Debentures, due 2043 [Member]
BHE Debt [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		3.75%
Subsequent Event [Member] | Junior Subordinated Debt [Member] | Berkshire Hathaway Energy [Member] | BHE Junior Subordinated Debentures, due 2044 [Member]
BHE Debt [Line Items]
Amount to be redeemed	$ 0

Subsidiary Debt - Summary (Deta

Subsidiary Debt - Summary (Details) - USD ($) $ in Millions		Feb. 28, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value			$ 36,295
Other Long-term Debt, Noncurrent			26,748	$ 26,066
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value			27,476
Other Long-term Debt, Current			606	1,148
Other Long-term Debt, Noncurrent			26,748	26,066
Other long-term debt			27,354	27,214
Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			7,120
Other long-term debt			7,079	7,159
Eligible Property Subject To Lien Of Mortgages			26,000
Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			4,657
Other long-term debt			4,592	4,560
Letters of credit supporting tax-exempt bond obligations [Member] | Letter of Credit [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount			$ 255	$ 310
Maximum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate			0.22%	0.22%
Minimum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate			0.01%	0.02%
PacifiCorp [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount			$ 255	$ 310
Eligible Property Subject To Lien Of Mortgages			26,000
PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			7,120
Other long-term debt			7,079	7,159
PacifiCorp [Member] | Letters of credit supporting tax-exempt bond obligations [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount			255	310
MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			4,332
Other long-term debt			4,301	$ 4,271
Eligible Property Subject To Lien Of Mortgages			$ 15,000
First Mortgage Bonds, 3.85% To 8.53%, Due Through 2021 [Member] | Maximum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			8.53%	8.53%
First Mortgage Bonds, 3.85% To 8.53%, Due Through 2021 [Member] | Minimum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			3.85%	3.85%
First Mortgage Bonds, 3.85% To 8.53%, Due Through 2021 [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			$ 1,272
First Mortgage Bonds, 3.85% To 8.53%, Due Through 2021 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			1,272
Other long-term debt			$ 1,269	$ 1,271
First Mortgage Bonds, 2.95% To 8.27%, Due 2022 To 2026 [Member] | Maximum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			8.27%	8.27%
First Mortgage Bonds, 2.95% To 8.27%, Due 2022 To 2026 [Member] | Minimum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			2.95%	2.95%
First Mortgage Bonds, 2.95% To 8.27%, Due 2022 To 2026 [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			$ 1,829
First Mortgage Bonds, 2.95% To 8.27%, Due 2022 To 2026 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			1,829
Other long-term debt			$ 1,820	$ 1,819
First Mortgage Bonds, 7.70%, Due 2031 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			7.70%	7.70%
First Mortgage Bonds, 7.70%, Due 2031 [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			$ 300
First Mortgage Bonds, 7.70%, Due 2031 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			300
Other long-term debt			$ 298	$ 298
First Mortgage Bonds, 5.25% To 6.10%, Due 2034 to 2036 [Member] | Maximum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			6.10%	6.10%
First Mortgage Bonds, 5.25% To 6.10%, Due 2034 to 2036 [Member] | Minimum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			5.25%	5.25%
First Mortgage Bonds, 5.25% To 6.10%, Due 2034 to 2036 [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			$ 850
First Mortgage Bonds, 5.25% To 6.10%, Due 2034 to 2036 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			850
Other long-term debt			$ 843	$ 843
First Mortgage Bonds, 5.75% To 6.35%, Due 2037 To 2039 [Member] | Maximum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			6.35%	6.35%
First Mortgage Bonds, 5.75% To 6.35%, Due 2037 To 2039 [Member] | Minimum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			5.75%	5.75%
First Mortgage Bonds, 5.75% To 6.35%, Due 2037 To 2039 [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			$ 2,150
First Mortgage Bonds, 5.75% To 6.35%, Due 2037 To 2039 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			2,150
Other long-term debt			$ 2,134	$ 2,133
First Mortgage Bonds, 4.10%, Due 2042 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			4.10%	4.10%
First Mortgage Bonds, 4.10%, Due 2042 [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			$ 300
Debt Instrument, Interest Rate, Stated Percentage			4.10%	4.10%
First Mortgage Bonds, 4.10%, Due 2042 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			$ 300
Other long-term debt			297	$ 297
Tax-exempt bond obligations, variable rate series, due 2017 to 2018 [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			91
Tax-exempt bond obligations, variable rate series, due 2017 to 2018 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value	[1]		91
Other long-term debt	[1]		91	91
Tax-exempt bond obligations, variable rate series, due 2018 to 2025 [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value	[2]		108
Tax-exempt bond obligations, variable rate series, due 2018 to 2025 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value	[1]		108
Other long-term debt	[1]		108	107
Variable-rate tax-exempt obligation series due 2024 [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value	[2],[3]		143
Variable-rate tax-exempt obligation series due 2024 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value	[1],[4]		143
Other long-term debt	[1],[4]		142	196
Variable-rate tax-exempt obligation series due 2024 to 2025 [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value	[3]		50
Variable-rate tax-exempt obligation series due 2024 to 2025 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value	[4]		50
Other long-term debt	[4]		$ 50	59
Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member] | Maximum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			14.61%
Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member] | Minimum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			8.75%
Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member] | PacifiCorp [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value			$ 27
Other long-term debt			$ 27	$ 45
Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member] | PacifiCorp [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			14.61%	14.61%
Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member] | PacifiCorp [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			8.75%	8.75%
Capital lease obligations, 8.75% to 15.678%, due through 2035 [Member] | Maximum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				15.678%
Capital lease obligations, 8.75% to 15.678%, due through 2035 [Member] | Minimum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				8.75%
Senior Notes, 6.927%, due 2029 [Member] | MidAmerican Funding LLC [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 325
Other long-term debt			$ 291	$ 289
Debt Instrument, Interest Rate, Stated Percentage			6.927%	6.927%
Tax-exempt bond obligations, variable rate, due 2016-2046 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate			0.76%
Par value			$ 220
Other long-term debt			219	$ 194
Tax-exempt bond obligations, variable rate, due 2016-2038 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate				0.03%
MEC First Mortgage Bonds, 2.40%, Due March 2019 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			500
Other long-term debt			$ 499	$ 499
Debt Instrument, Interest Rate, Stated Percentage			2.40%	2.40%
MEC First Mortgage Bonds, 3.70%, Due September 2023 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 250
Other long-term debt			$ 248	$ 248
Debt Instrument, Interest Rate, Stated Percentage			3.70%	3.70%
MEC First Mortgage Bonds, 3.50%, Due October 2024 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 500
Other long-term debt			$ 501	$ 502
Debt Instrument, Interest Rate, Stated Percentage			3.50%	3.50%
MEC First Mortgage Bonds, 4.80%, Due September 2043 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 350
Other long-term debt			$ 345	$ 345
Debt Instrument, Interest Rate, Stated Percentage			4.80%	4.80%
MEC First Mortgage Bonds, 4.40%, Due October 2044 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 400
Other long-term debt			$ 394	$ 394
Debt Instrument, Interest Rate, Stated Percentage			4.40%	4.40%
MEC First Mortgage Bonds, 4.25%, Due May 2046 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 450
Other long-term debt			$ 445	$ 444
Debt Instrument, Interest Rate, Stated Percentage			4.25%	0.00%
MEC Notes, 5.95% Series, due 2017 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 250
Other long-term debt			$ 250	$ 250
Debt Instrument, Interest Rate, Stated Percentage			5.95%	5.95%
MEC Notes, 5.3% Series, due 2018 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 350
Other long-term debt			$ 350	$ 349
Debt Instrument, Interest Rate, Stated Percentage			5.30%	5.30%
MEC Notes, 6.75% Series, due 2031 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 400
Other long-term debt			$ 396	$ 395
Debt Instrument, Interest Rate, Stated Percentage			6.75%	6.75%
MEC Notes, 5.75% Series, due 2035 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 300
Other long-term debt			$ 298	$ 298
Debt Instrument, Interest Rate, Stated Percentage			5.75%	5.75%
MEC Notes, 5.8% Series, due 2036 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 350
Other long-term debt			$ 347	$ 347
Debt Instrument, Interest Rate, Stated Percentage			5.80%	5.80%
MEC Transmission Upgrade Obligations, 4.45% and 3.42% Due Through 2035 and 2036 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			$ 10
Other long-term debt			7	$ 4
Capital Lease Obligations, 4.16%, Due Through 2020 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value			2
Other long-term debt			$ 2	$ 2
Subsequent Event [Member] | MEC First Mortgage Bonds, 3.10%, Due May 2027 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value		$ 375
Debt Instrument, Interest Rate, Stated Percentage		3.10%
Subsequent Event [Member] | MEC Notes, 5.95% Series, due 2017 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.95%
Debt Instrument, Repurchased Face Amount		$ 250
Subsequent Event [Member] | MEC First Mortgage Bonds, 3.95%, Due 2047 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value		$ 475
Debt Instrument, Interest Rate, Stated Percentage		3.95%
[1]	Supported by $255 million and $310 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2016 and 2015, respectively.
[2]	1)Supported by $255 million and $310 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2016 and 2015, respectively.
[3]	2)Secured by pledged first mortgage bonds registered to and held by the tax-exempt bond trustee generally with the same interest rates, maturity dates and redemption provisions as the tax-exempt bond obligations.
[4]	Secured by pledged first mortgage bonds registered to and held by the tax-exempt bond trustee generally with the same interest rates, maturity dates and redemption provisions as the tax-exempt bond obligations.

Subsidiary Debt - NV Energy (De

Subsidiary Debt - NV Energy (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value	$ 36,295
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	27,476
Other long-term debt	27,354	$ 27,214
NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	4,569
Other long-term debt	4,582	4,860
NV Energy, Inc. [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Senior Notes, 6.250%, due 2020 [Member]
Debt Instrument [Line Items]
Par value	315
Other long-term debt	$ 363	$ 373
Debt Instrument, Interest Rate, Stated Percentage	6.25%	6.25%
Nevada Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 3,100
Eligible Property Subject To Lien Of Mortgages	$ 8,900
Nevada Power Company [Member] | Mortgage Securities, 5.950%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.95%	5.95%
Nevada Power Company [Member] | Mortgage Securities, 6.500%, Series O due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.50%	6.50%
Nevada Power Company [Member] | Mortgage Securities, 6.500%, Series S due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.50%	6.50%
Nevada Power Company [Member] | Mortgage Securities, 7.125%, Series V due 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.125%	7.125%
Nevada Power Company [Member] | Mortgage Securities, 6.650%, Series N due 2036 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.65%	6.65%
Nevada Power Company [Member] | Mortgage Securities, 6.750%, Series R due 2037 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.75%	6.75%
Nevada Power Company [Member] | Mortgage Securities, 5.375%, Series X due 2040 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.375%	5.375%
Nevada Power Company [Member] | Mortgage Securities, 5.450%, Series Y due 2041 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.45%	5.45%
Nevada Power Company [Member] | NV Energy [Member] | Mortgage Securities, 5.950%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Par value	$ 0
Nevada Power Company [Member] | NV Energy [Member] | Mortgage Securities, 6.500%, Series O due 2018 [Member]
Debt Instrument [Line Items]
Par value	324
Nevada Power Company [Member] | NV Energy [Member] | Mortgage Securities, 6.500%, Series S due 2018 [Member]
Debt Instrument [Line Items]
Par value	499
Nevada Power Company [Member] | NV Energy [Member] | Mortgage Securities, 7.125%, Series V due 2019 [Member]
Debt Instrument [Line Items]
Par value	500
Nevada Power Company [Member] | NV Energy [Member] | Mortgage Securities, 6.650%, Series N due 2036 [Member]
Debt Instrument [Line Items]
Par value	367
Nevada Power Company [Member] | NV Energy [Member] | Mortgage Securities, 6.750%, Series R due 2037 [Member]
Debt Instrument [Line Items]
Par value	349
Nevada Power Company [Member] | NV Energy [Member] | Mortgage Securities, 5.375%, Series X due 2040 [Member]
Debt Instrument [Line Items]
Par value	250
Nevada Power Company [Member] | NV Energy [Member] | Mortgage Securities, 5.450%, Series Y due 2041 [Member]
Debt Instrument [Line Items]
Par value	250
Nevada Power Company [Member] | NV Energy [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Par value	38
Nevada Power Company [Member] | NV Energy [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Par value	38
Nevada Power Company [Member] | NV Energy [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Par value	485
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	3,100
Other long-term debt	3,066	$ 3,285
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage Securities, 5.950%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 0	$ 210
Debt Instrument, Interest Rate, Stated Percentage	5.95%	5.95%
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage Securities, 6.500%, Series O due 2018 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 324	$ 323
Debt Instrument, Interest Rate, Stated Percentage	6.50%	6.50%
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage Securities, 6.500%, Series S due 2018 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 498	$ 498
Debt Instrument, Interest Rate, Stated Percentage	6.50%	6.50%
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage Securities, 7.125%, Series V due 2019 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 499	$ 499
Debt Instrument, Interest Rate, Stated Percentage	7.125%	7.125%
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage Securities, 6.650%, Series N due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 357	$ 356
Debt Instrument, Interest Rate, Stated Percentage	6.65%	6.65%
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage Securities, 6.750%, Series R due 2037 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 345	$ 345
Debt Instrument, Interest Rate, Stated Percentage	6.75%	6.75%
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage Securities, 5.375%, Series X due 2040 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 247	$ 247
Debt Instrument, Interest Rate, Stated Percentage	5.375%	5.375%
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage Securities, 5.450%, Series Y due 2041 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 236	$ 235
Debt Instrument, Interest Rate, Stated Percentage	5.45%	5.45%
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 38	$ 38
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt	37	37
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 485	$ 497
Nevada Power Company [Member] | Minimum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	1.89%	0.672%
Nevada Power Company [Member] | Minimum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	1.89%	0.672%
Nevada Power Company [Member] | Minimum [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	2.75%	2.75%
Nevada Power Company [Member] | Minimum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	1.89%	0.672%
Nevada Power Company [Member] | Minimum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	1.89%	0.672%
Nevada Power Company [Member] | Minimum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	2.75%	2.75%
Nevada Power Company [Member] | Maximum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	1.928%	1.055%
Nevada Power Company [Member] | Maximum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	1.928%	1.055%
Nevada Power Company [Member] | Maximum [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	11.60%	11.60%
Nevada Power Company [Member] | Maximum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	1.928%	1.055%
Nevada Power Company [Member] | Maximum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	1.928%	1.055%
Nevada Power Company [Member] | Maximum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	11.60%	11.60%
Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 1,154
Eligible Property Subject To Lien Of Mortgages	$ 3,800
Sierra Pacific Power Company [Member] | Mortgage securities, 6.000%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.00%	6.00%
Sierra Pacific Power Company [Member] | Mortgage securities, 3.375%, Series T due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.375%	3.375%
Sierra Pacific Power Company [Member] | Mortgage securities, 2.600%, Series U due 2026 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.60%
Sierra Pacific Power Company [Member] | Mortgage securities, 6.750%, Series P due 2037 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.75%	6.75%
Sierra Pacific Power Company [Member] | NV Energy [Member] | Mortgage securities, 6.000%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Par value	$ 0
Sierra Pacific Power Company [Member] | NV Energy [Member] | Mortgage securities, 3.375%, Series T due 2023 [Member]
Debt Instrument [Line Items]
Par value	250
Sierra Pacific Power Company [Member] | NV Energy [Member] | Mortgage securities, 2.600%, Series U due 2026 [Member]
Debt Instrument [Line Items]
Par value	400
Sierra Pacific Power Company [Member] | NV Energy [Member] | Mortgage securities, 6.750%, Series P due 2037 [Member]
Debt Instrument [Line Items]
Par value	252
Sierra Pacific Power Company [Member] | NV Energy [Member] | Pollution Control Refunding Revenue Bonds, 1.250%, Series 2016A, due 2029 [Member]
Debt Instrument [Line Items]
Par value	20
Sierra Pacific Power Company [Member] | NV Energy [Member] | Gas facilities refunding revenue bonds, 1.500%, series 2016A, due 2031 [Member]
Debt Instrument [Line Items]
Par value	58
Sierra Pacific Power Company [Member] | NV Energy [Member] | Gas and water facilities refunding revenue bonds, 3.000% series 2016B, due 2036 [Member]
Debt Instrument [Line Items]
Par value	60
Sierra Pacific Power Company [Member] | NV Energy [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006A due 2031 [Member]
Debt Instrument [Line Items]
Par value	0
Sierra Pacific Power Company [Member] | NV Energy [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006B due 2036 [Member]
Debt Instrument [Line Items]
Par value	0
Sierra Pacific Power Company [Member] | NV Energy [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006C due 2036 [Member]
Debt Instrument [Line Items]
Par value	0
Sierra Pacific Power Company [Member] | NV Energy [Member] | Water facilities refunding revenue bonds, series 2016C, due 2036 [Member]
Debt Instrument [Line Items]
Par value	30
Sierra Pacific Power Company [Member] | NV Energy [Member] | Water facilities refunding revenue bonds, series 2016D, due 2036 [Member]
Debt Instrument [Line Items]
Par value	25
Sierra Pacific Power Company [Member] | NV Energy [Member] | Water facilities refunding revenue bonds, series 2016E, due 2036 [Member]
Debt Instrument [Line Items]
Par value	25
Sierra Pacific Power Company [Member] | NV Energy [Member] | Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member]
Debt Instrument [Line Items]
Par value	34
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	1,154
Other long-term debt	1,153	$ 1,202
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage securities, 6.000%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 0	$ 450
Debt Instrument, Interest Rate, Stated Percentage	6.00%	6.00%
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage securities, 3.375%, Series T due 2023 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 248	$ 248
Debt Instrument, Interest Rate, Stated Percentage	3.375%	3.375%
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage securities, 2.600%, Series U due 2026 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 395	$ 0
Debt Instrument, Interest Rate, Stated Percentage		2.60%
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage securities, 6.750%, Series P due 2037 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 255	$ 255
Debt Instrument, Interest Rate, Stated Percentage	6.75%	6.75%
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Refunding Revenue Bonds, 1.250%, Series 2016A, due 2029 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 20	$ 0
Debt Instrument, Interest Rate, Stated Percentage	1.25%	1.25%
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Gas facilities refunding revenue bonds, 1.500%, series 2016A, due 2031 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 58	$ 0
Debt Instrument, Interest Rate, Stated Percentage	1.50%	1.50%
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Gas and water facilities refunding revenue bonds, 3.000% series 2016B, due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 64	$ 0
Debt Instrument, Interest Rate, Stated Percentage	3.00%	3.00%
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006A due 2031 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 0	$ 58
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006B due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt	0	74
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006C due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt	0	80
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016C, due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt	29	0
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016D, due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt	25	0
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016E, due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt	25	0
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 34	$ 37
Sierra Pacific Power Company [Member] | Minimum [Member] | Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	2.70%	2.70%
Sierra Pacific Power Company [Member] | Minimum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006A due 2031 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.788%	0.733%
Sierra Pacific Power Company [Member] | Minimum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006B due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.788%	0.733%
Sierra Pacific Power Company [Member] | Minimum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006C due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.788%	0.733%
Sierra Pacific Power Company [Member] | Minimum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016C, due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.788%	0.733%
Sierra Pacific Power Company [Member] | Minimum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016D, due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.788%	0.733%
Sierra Pacific Power Company [Member] | Minimum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016E, due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.788%	0.733%
Sierra Pacific Power Company [Member] | Minimum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	2.70%	2.70%
Sierra Pacific Power Company [Member] | Maximum [Member] | Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	10.13%	8.548%
Sierra Pacific Power Company [Member] | Maximum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006A due 2031 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.80%	1.054%
Sierra Pacific Power Company [Member] | Maximum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006B due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.80%	1.054%
Sierra Pacific Power Company [Member] | Maximum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, 0.464% to 0.466%, Series 2006C due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.80%	1.054%
Sierra Pacific Power Company [Member] | Maximum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016C, due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.80%	1.054%
Sierra Pacific Power Company [Member] | Maximum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016D, due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.80%	1.054%
Sierra Pacific Power Company [Member] | Maximum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016E, due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	0.80%	1.054%
Sierra Pacific Power Company [Member] | Maximum [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	10.13%	8.548%

Subsidiary Debt - Northern Powe

Subsidiary Debt - Northern Powergrid (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value		$ 36,295
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		27,476
Other long-term debt		27,354	$ 27,214
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[1]	2,351
Other long-term debt		2,379	2,772
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 8.875%, due 2020 [Member]
Debt Instrument [Line Items]
Par value	[1]	123
Other long-term debt		$ 136	$ 162
Debt Instrument, Interest Rate, Stated Percentage		8.875%	8.875%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 9.25%, due 2020 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 247
Other long-term debt		$ 259	$ 315
Debt Instrument, Interest Rate, Stated Percentage		9.25%	9.25%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | European Investment Bank loans, 3.901% to 4.586%, due 2018 to 2022 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 333
Other long-term debt		$ 333	$ 398
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | European Investment Bank loans, 3.901% to 4.586%, due 2018 to 2022 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.901%	3.901%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | European Investment Bank loans, 3.901% to 4.586%, due 2018 to 2022 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.586%	4.586%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 7.25%, due 2022 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 247
Other long-term debt		$ 257	$ 306
Debt Instrument, Interest Rate, Stated Percentage		7.25%	7.25%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 2.50%, due 2025 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 185
Other long-term debt		$ 182	$ 217
Debt Instrument, Interest Rate, Stated Percentage		2.50%	2.50%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | European Investment Bank loan, 2.073%, due 2025 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 62
Other long-term debt		62	$ 0
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | European Investment Bank loans, 2.564%, due 2017 [Member]
Debt Instrument [Line Items]
Par value	[1]	308
Other long-term debt		$ 308	$ 368
Debt Instrument, Interest Rate, Stated Percentage		2.564%	2.564%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 7.25%, due 2028 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 229
Other long-term debt		$ 234	$ 280
Debt Instrument, Interest Rate, Stated Percentage		7.25%	7.25%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 5.125%, due 2035 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 247
Other long-term debt		$ 243	$ 291
Debt Instrument, Interest Rate, Stated Percentage		5.125%	5.125%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 5.125%, due 2035 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 185
Other long-term debt		$ 183	$ 218
Debt Instrument, Interest Rate, Stated Percentage		5.125%	5.125%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 4.375%, due 2032 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 185
Other long-term debt		$ 182	$ 217
Debt Instrument, Interest Rate, Stated Percentage		4.375%	4.375%
[1]	The par values for these debt instruments are denominated in sterling.

Subsidiary Debt - BHE Pipeline

Subsidiary Debt - BHE Pipeline Group (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value	$ 36,295
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	27,476
Other long-term debt	27,354	$ 27,214
BHE Pipeline Group [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	995
Other long-term debt	990	1,040
Northern Natural Gas [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	800
Other long-term debt	795	795
Northern Natural Gas [Member] | Subsidiary Debt [Member] | Senior Notes, 5.75%, due 2018 [Member]
Debt Instrument [Line Items]
Par value	200
Other long-term debt	199	199
Northern Natural Gas [Member] | Subsidiary Debt [Member] | Senior Notes, 4.25%, due 2021 [Member]
Debt Instrument [Line Items]
Par value	200
Other long-term debt	199	199
Northern Natural Gas [Member] | Subsidiary Debt [Member] | Senior Bonds, 5.8%, due 2037 [Member]
Debt Instrument [Line Items]
Par value	150
Other long-term debt	149	149
Northern Natural Gas [Member] | Subsidiary Debt [Member] | Senior Bonds, 4.1%, due 2042 [Member]
Debt Instrument [Line Items]
Par value	250
Other long-term debt	248	248
Kern River [Member] | Subsidiary Debt [Member] | Senior Notes, 4.893%, due 2018 [Member]
Debt Instrument [Line Items]
Par value	195
Other long-term debt	$ 195	$ 245
Northern Natural Gas [Member] | BHE Pipeline Group [Member] | Subsidiary Debt [Member] | Senior Notes, 5.75%, due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.75%	5.75%
Northern Natural Gas [Member] | BHE Pipeline Group [Member] | Subsidiary Debt [Member] | Senior Notes, 4.25%, due 2021 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.25%	4.25%
Northern Natural Gas [Member] | BHE Pipeline Group [Member] | Subsidiary Debt [Member] | Senior Bonds, 5.8%, due 2037 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.80%	5.80%
Northern Natural Gas [Member] | BHE Pipeline Group [Member] | Subsidiary Debt [Member] | Senior Bonds, 4.1%, due 2042 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.10%	4.10%
Kern River [Member] | BHE Pipeline Group [Member] | Subsidiary Debt [Member] | Senior Notes, 4.893%, due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.893%	4.893%
Kern River [Member] | Letter of Credit [Member] | BHE Pipeline Group [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount	$ 35	$ 33

Subsidiary Debt Subsidiary Debt

Subsidiary Debt Subsidiary Debt - AltaLink (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value		$ 36,295
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		27,476
Other long-term debt		27,354	$ 27,214
ALP Investments [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[1]	447
Other long-term debt		453	556
ALP Investments [Member] | Subsidiary Debt [Member] | Series 09-1 Senior Bonds, 5.207%, due 2016 [Member]
Debt Instrument [Line Items]
Par value	[1]	0
Other long-term debt		$ 0	$ 112
Debt Instrument, Interest Rate, Stated Percentage		5.207%	5.207%
ALP Investments [Member] | Subsidiary Debt [Member] | Series 12-1 Senior Bonds, 3.674%, due 2019 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 149
Other long-term debt		$ 153	$ 151
Debt Instrument, Interest Rate, Stated Percentage		3.674%	3.674%
ALP Investments [Member] | Subsidiary Debt [Member] | Series 13-1 Senior Bonds, 3.265%, due 2020 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 149
Other long-term debt		$ 152	$ 149
Debt Instrument, Interest Rate, Stated Percentage		3.265%	3.265%
ALP Investments [Member] | Subsidiary Debt [Member] | Series 15-1 Senior Bonds, 2.244%, due 2022 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 149
Other long-term debt		$ 148	$ 144
Debt Instrument, Interest Rate, Stated Percentage		2.244%	2.244%
AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 3,608
Other long-term debt		3,592	$ 2,911
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2008-1 Notes, 5.243%, due 2018 [Member]
Debt Instrument [Line Items]
Par value	[1]	149
Other long-term debt		$ 148	$ 145
Debt Instrument, Interest Rate, Stated Percentage		5.243%	5.243%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2013-2 Notes, 3.621%, due 2020 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 93
Other long-term debt		$ 93	$ 90
Debt Instrument, Interest Rate, Stated Percentage		3.621%	3.621%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2012-2 Notes, 2.978%, due 2022 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 204
Other long-term debt		$ 204	$ 198
Debt Instrument, Interest Rate, Stated Percentage		2.978%	2.978%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2013-4 Notes, 3.668%, due 2023 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 372
Other long-term debt		$ 371	$ 360
Debt Instrument, Interest Rate, Stated Percentage		3.668%	3.668%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2014-1 Notes, 3.399%, due 2024 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 260
Other long-term debt		$ 260	$ 252
Debt Instrument, Interest Rate, Stated Percentage		3.399%	3.399%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2016-1 Notes, 2.747%, due 2026 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 260
Other long-term debt		$ 259	$ 0
Debt Instrument, Interest Rate, Stated Percentage		2.747%	0.00%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2006-1 Notes, 5.249%, due 2036 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 112
Other long-term debt		$ 111	$ 108
Debt Instrument, Interest Rate, Stated Percentage		5.249%	5.249%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2010-1 Notes, 5.381%, due 2040 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 93
Other long-term debt		$ 93	$ 90
Debt Instrument, Interest Rate, Stated Percentage		5.381%	5.381%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2010-2 Notes, 4.872%, due 2040 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 112
Other long-term debt		$ 111	$ 108
Debt Instrument, Interest Rate, Stated Percentage		4.872%	4.872%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2011-1 Notes, 4.462%, due 2041 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 205
Other long-term debt		$ 204	$ 198
Debt Instrument, Interest Rate, Stated Percentage		4.462%	4.462%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2012-1 Notes, 3.99%, due 2042 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 391
Other long-term debt		$ 385	$ 374
Debt Instrument, Interest Rate, Stated Percentage		3.99%	3.99%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2013-3 Notes, 4.922%, due 2043 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 260
Other long-term debt		$ 260	$ 252
Debt Instrument, Interest Rate, Stated Percentage		4.922%	4.922%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2014-3 Notes, 4.054%, due 2044 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 219
Other long-term debt		$ 218	$ 212
Debt Instrument, Interest Rate, Stated Percentage		4.054%	4.054%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2015-1 Notes, 4.090%, due 2045 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 260
Other long-term debt		$ 259	$ 251
Debt Instrument, Interest Rate, Stated Percentage		4.09%	4.09%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2016-2 Notes, 3.717%, due 2046 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 335
Other long-term debt		$ 333	$ 0
Debt Instrument, Interest Rate, Stated Percentage		3.717%	0.00%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2013-1 Notes, 4.446%, due 2053 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 186
Other long-term debt		$ 186	$ 180
Debt Instrument, Interest Rate, Stated Percentage		4.446%	4.446%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2014-2 Notes, 4.274%, due 2064 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 97
Other long-term debt		$ 97	$ 93
Debt Instrument, Interest Rate, Stated Percentage		4.274%	4.274%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Construction Loan, 4.950%, due 2021 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 13
Other long-term debt		$ 13	$ 0
Debt Instrument, Interest Rate, Stated Percentage		4.95%	0.00%
BHE Transmission [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 4,068
Other long-term debt		$ 4,058	$ 3,467
[1]	(1)The par values for these debt instruments are denominated in Canadian dollars.

Subsidiary Debt - BHE Renewable

Subsidiary Debt - BHE Renewables (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value		$ 36,295
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		27,476
Other long-term debt		27,354	$ 27,214
BHE Renewables [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		3,716
Other long-term debt		$ 3,674	$ 3,356
BHE Renewables [Member] | Subsidiary Debt [Member] | Minimum [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Fixed Interest, Percentage Rate		3.21%	3.55%
BHE Renewables [Member] | Subsidiary Debt [Member] | Maximum [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Fixed Interest, Percentage Rate		3.63%	3.63%
BHE Renewables [Member] | Subsidiary Debt [Member] | CE Generation Bonds 7.416% due 2018 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 67
Other long-term debt	[1]	$ 67	$ 97
Debt Instrument, Interest Rate, Stated Percentage		7.416%	7.416%
BHE Renewables [Member] | Subsidiary Debt [Member] | Salton Sea Funding Corporation Bonds 7.475% due 2018 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 30
Other long-term debt	[1]	$ 31	$ 51
Debt Instrument, Interest Rate, Stated Percentage		7.475%	7.475%
BHE Renewables [Member] | Subsidiary Debt [Member] | Cordova Funding Corporation Bonds, 8.48% to 9.07%, due 2019 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 96
Other long-term debt	[1]	$ 97	$ 113
BHE Renewables [Member] | Subsidiary Debt [Member] | Cordova Funding Corporation Bonds, 8.48% to 9.07%, due 2019 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.48%	8.48%
BHE Renewables [Member] | Subsidiary Debt [Member] | Cordova Funding Corporation Bonds, 8.48% to 9.07%, due 2019 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		9.07%	9.07%
BHE Renewables [Member] | Subsidiary Debt [Member] | Bishop Hill Holdings Senior Notes, 5.125%, due 2032 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 100
Other long-term debt	[1]	$ 99	$ 102
Debt Instrument, Interest Rate, Stated Percentage		5.125%	5.125%
BHE Renewables [Member] | Subsidiary Debt [Member] | Solar Star Funding, LLC Series A Senior Secured Notes, 3.950%, due June 2035 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 316
Other long-term debt	[1]	$ 311	$ 321
Debt Instrument, Interest Rate, Stated Percentage		3.95%	3.95%
BHE Renewables [Member] | Subsidiary Debt [Member] | Solar Star Funding, LLC Series A Senior Secured Notes, 5.375%, due June 2016 through June 2035 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 977
Other long-term debt	[1]	$ 966	$ 988
Debt Instrument, Interest Rate, Stated Percentage		5.375%	5.375%
BHE Renewables [Member] | Subsidiary Debt [Member] | Grande Prairie Wind, Senior Notes, 3.860%, due 2037 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 419
Other long-term debt		414	$ 0
BHE Renewables [Member] | Subsidiary Debt [Member] | Topaz Solar Farms Senior Notes, 5.75%, due 2039 [Member]
Debt Instrument [Line Items]
Par value	[1]	791
Other long-term debt	[1]	$ 780	$ 815
Debt Instrument, Interest Rate, Stated Percentage		5.75%	5.75%
BHE Renewables [Member] | Subsidiary Debt [Member] | Topaz Solar Farms Senior Notes, 4.875%, due 2039
Debt Instrument [Line Items]
Par value	[1]	$ 230
Other long-term debt	[1]	$ 229	$ 239
Debt Instrument, Interest Rate, Stated Percentage		4.875%	4.875%
BHE Renewables [Member] | Subsidiary Debt [Member] | Other debt obligations [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 22
Other long-term debt	[1]	22	$ 25
BHE Renewables [Member] | Subsidiary Debt [Member] | Pinyon Pines I and II Term Loans, due 2019 [Member]
Debt Instrument [Line Items]
Par value	[1],[2]	356
Other long-term debt	[1],[2]	$ 355	$ 378
Variable interest rate		2.62%	2.23%
Debt Instrument, Interest Rate, Stated Percentage		3.55%	3.55%
BHE Renewables [Member] | Subsidiary Debt [Member] | Wailuku Special Purpose Revenue Bonds, 0.09% due 2021 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 7
Other long-term debt	[1]	$ 7	$ 8
Debt Instrument, Interest Rate, Stated Percentage		0.90%	0.90%
BHE Renewables [Member] | Subsidiary Debt [Member] | TX Jumbo Road Term Loan, 3.626% due 2025 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 212
Other long-term debt	[1]	$ 206	$ 219
Debt Instrument, Interest Rate, Stated Percentage		3.626%	3.626%
BHE Renewables [Member] | Subsidiary Debt [Member] | Marshall Wind term loan, variable interest rate, due 2026 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 93
Other long-term debt		$ 90	$ 0
Debt Instrument, Interest Rate, Stated Percentage		3.212%	0.00%
[1]	Amortizes quarterly or semiannually.
[2]	The term loans have variable interest rates based on LIBOR plus a margin that varies during the terms of the agreements. The Company has entered into interest rate swaps that fix the interest rate on 75% of the Pinyon Pines outstanding debt and 100% of the TX Jumbo Road and Marshall Wind outstanding debt. The variable interest rate as of December 31, 2016 and 2015 was 2.62% and 2.23%, respectively, while the fixed interest rates ranged from 3.21% to 3.63% as of December 31, 2016, and 3.55% to 3.63% as of December 31, 2015.

Subsidiary Debt - Maturity Sche

Subsidiary Debt - Maturity Schedule (Details) $ in Millions	Dec. 31, 2016USD ($)
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 1,006
Long-term Debt, Maturities, Repayments of Principal in Year Two	3,544
Long-term Debt, Maturities, Repayments of Principal in Year Three	2,099
Long-term Debt, Maturities, Repayments of Principal in Year Four	1,552
Long-term Debt, Maturities, Repayments of Principal in Year Five	823
Long-term Debt, Maturities, Repayments of Principal after Year Five	27,271
Par value	36,295
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	27,476
PacifiCorp [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	58
Long-term Debt, Maturities, Repayments of Principal in Year Two	588
Long-term Debt, Maturities, Repayments of Principal in Year Three	352
Long-term Debt, Maturities, Repayments of Principal in Year Four	40
Long-term Debt, Maturities, Repayments of Principal in Year Five	425
Long-term Debt, Maturities, Repayments of Principal after Year Five	5,657
Par value	7,120
MidAmerican Funding [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	251
Long-term Debt, Maturities, Repayments of Principal in Year Two	351
Long-term Debt, Maturities, Repayments of Principal in Year Three	500
Long-term Debt, Maturities, Repayments of Principal in Year Four	2
Long-term Debt, Maturities, Repayments of Principal in Year Five	1
Long-term Debt, Maturities, Repayments of Principal after Year Five	3,552
Par value	4,657
NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	18
Long-term Debt, Maturities, Repayments of Principal in Year Two	840
Long-term Debt, Maturities, Repayments of Principal in Year Three	519
Long-term Debt, Maturities, Repayments of Principal in Year Four	336
Long-term Debt, Maturities, Repayments of Principal in Year Five	27
Long-term Debt, Maturities, Repayments of Principal after Year Five	2,829
Par value	4,569
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	0
Long-term Debt, Maturities, Repayments of Principal in Year Two	49
Long-term Debt, Maturities, Repayments of Principal in Year Three	49
Long-term Debt, Maturities, Repayments of Principal in Year Four	418
Long-term Debt, Maturities, Repayments of Principal in Year Five	0
Long-term Debt, Maturities, Repayments of Principal after Year Five	1,835
Par value	2,351	[1]
BHE Pipeline Group [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	66
Long-term Debt, Maturities, Repayments of Principal in Year Two	329
Long-term Debt, Maturities, Repayments of Principal in Year Three	0
Long-term Debt, Maturities, Repayments of Principal in Year Four	0
Long-term Debt, Maturities, Repayments of Principal in Year Five	200
Long-term Debt, Maturities, Repayments of Principal after Year Five	400
Par value	995
BHE Transmission [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	0
Long-term Debt, Maturities, Repayments of Principal in Year Two	151
Long-term Debt, Maturities, Repayments of Principal in Year Three	151
Long-term Debt, Maturities, Repayments of Principal in Year Four	245
Long-term Debt, Maturities, Repayments of Principal in Year Five	3
Long-term Debt, Maturities, Repayments of Principal after Year Five	3,518
Par value	4,068	[2]
BHE Renewables [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	213
Long-term Debt, Maturities, Repayments of Principal in Year Two	236
Long-term Debt, Maturities, Repayments of Principal in Year Three	528
Long-term Debt, Maturities, Repayments of Principal in Year Four	161
Long-term Debt, Maturities, Repayments of Principal in Year Five	167
Long-term Debt, Maturities, Repayments of Principal after Year Five	2,411
Par value	3,716
Berkshire Hathaway Energy [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	400
Long-term Debt, Maturities, Repayments of Principal in Year Two	1,000
Long-term Debt, Maturities, Repayments of Principal in Year Three	0
Long-term Debt, Maturities, Repayments of Principal in Year Four	350
Long-term Debt, Maturities, Repayments of Principal in Year Five	0
Long-term Debt, Maturities, Repayments of Principal after Year Five	6,125
Par value	7,875
Berkshire Hathaway Energy [Member] | Junior Subordinated Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	0
Long-term Debt, Maturities, Repayments of Principal in Year Two	0
Long-term Debt, Maturities, Repayments of Principal in Year Three	0
Long-term Debt, Maturities, Repayments of Principal in Year Four	0
Long-term Debt, Maturities, Repayments of Principal in Year Five	0
Long-term Debt, Maturities, Repayments of Principal after Year Five	944
Par value	$ 944
[1]	The par values for these debt instruments are denominated in sterling.
[2]	(1)The par values for these debt instruments are denominated in Canadian dollars.

Subsidiary Debt Subsidiary D133

Subsidiary Debt Subsidiary Debt - Pacificorp (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value		$ 36,295
Long-term Debt		36,116	$ 37,972
PacifiCorp [Member]
Debt Instrument [Line Items]
Long-term Debt		7,052	7,114
Long-term Debt and Capital Lease Obligations, Principal Amount		7,120
Current portion of long-term debt and capital lease obligations		58	68
Long-term debt and capital lease obligations		7,021	7,078
Total long-term debt and capital lease obligations		7,079	7,146
Letters of Credit Outstanding, Amount		255	310
Maximum amount of additional long-term debt approved by regulators		1,325
Eligible Property Subject To Lien Of Mortgages		26,000
Capital Leases, Balance Sheet, Assets by Major Class, Net		27	32
PacifiCorp [Member] | Letters of credit supporting tax-exempt bond obligations [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		$ 255	$ 310
PacifiCorp [Member] | First Mortgage Bonds, 5.50% To 8.635%, Due Through 2019 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.85%	3.85%
PacifiCorp [Member] | First Mortgage Bonds, 5.50% To 8.635%, Due Through 2019 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.53%	8.53%
PacifiCorp [Member] | First Mortgage Bonds, 3.85% To 8.53%, Due Through 2021 [Member]
Debt Instrument [Line Items]
Par value		$ 1,272
Long-term Debt		$ 1,269	$ 1,271
Long-term Debt, Weighted Average Interest Rate		5.10%	5.10%
PacifiCorp [Member] | First Mortgage Bonds, 2.95% To 8.27%, Due 2022 To 2026 [Member]
Debt Instrument [Line Items]
Par value		$ 1,829
Long-term Debt		$ 1,820	$ 1,819
Long-term Debt, Weighted Average Interest Rate		4.10%	4.10%
PacifiCorp [Member] | First Mortgage Bonds, 7.70%, Due 2031 [Member]
Debt Instrument [Line Items]
Par value		$ 300
Long-term Debt		$ 298	$ 298
Long-term Debt, Weighted Average Interest Rate		7.70%	7.70%
PacifiCorp [Member] | First Mortgage Bonds, 5.25% To 6.10%, Due 2034 to 2036 [Member]
Debt Instrument [Line Items]
Par value		$ 850
Long-term Debt		$ 843	$ 843
Long-term Debt, Weighted Average Interest Rate		5.80%	5.80%
PacifiCorp [Member] | First Mortgage Bonds, 5.75% To 6.35%, Due 2037 To 2039 [Member]
Debt Instrument [Line Items]
Par value		$ 2,150
Long-term Debt		$ 2,134	$ 2,133
Long-term Debt, Weighted Average Interest Rate		6.00%	6.00%
PacifiCorp [Member] | First Mortgage Bonds, 4.10%, Due 2042 [Member]
Debt Instrument [Line Items]
Par value		$ 300
Long-term Debt		$ 297	$ 297
Long-term Debt, Weighted Average Interest Rate		4.10%	4.10%
Debt Instrument, Interest Rate, Stated Percentage		4.10%	4.10%
PacifiCorp [Member] | Tax-exempt bond obligations, variable rate series, due 2018 to 2025 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 108
Long-term Debt	[1]	$ 108	$ 107
Long-term Debt, Weighted Average Interest Rate	[1]	0.74%	0.01%
PacifiCorp [Member] | Variable-rate tax-exempt obligation series due 2024 [Member]
Debt Instrument [Line Items]
Par value	[1],[2]	$ 143
Long-term Debt	[1],[2]	$ 142	$ 196
Long-term Debt, Weighted Average Interest Rate	[1],[2]	0.70%	0.02%
PacifiCorp [Member] | Variable-rate tax-exempt obligation series due 2024 to 2025 [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 50
Long-term Debt	[2]	$ 50	$ 59
Long-term Debt, Weighted Average Interest Rate	[2]	0.80%	0.21%
PacifiCorp [Member] | Tax-exempt bond obligations, variable rate series, due 2017 to 2018 [Member]
Debt Instrument [Line Items]
Par value		$ 91
Long-term Debt		$ 91	$ 91
Long-term Debt, Weighted Average Interest Rate		0.85%	0.22%
PacifiCorp [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Par value		$ 7,093
Long-term Debt		$ 7,052	$ 7,114
PacifiCorp [Member] | Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member]
Debt Instrument [Line Items]
Long-term Debt, Weighted Average Interest Rate		11.09%	11.25%
Capital Lease Obligations		$ 27	$ 32
PacifiCorp [Member] | Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.75%	8.75%
PacifiCorp [Member] | Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		14.61%	14.61%
PacifiCorp [Member] | First Mortgage Bonds, 2.95% To 8.53%, Due 2021 To 2025 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		2.95%	2.95%
PacifiCorp [Member] | First Mortgage Bonds, 2.95% To 8.53%, Due 2021 To 2025 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.27%	8.27%
PacifiCorp [Member] | First Mortgage Bonds, 6.71%, Due 2026 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.70%	7.70%
PacifiCorp [Member] | First Mortgage Bonds, 5.25% To 7.70%, Due 2031 To 2035 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.25%	5.25%
PacifiCorp [Member] | First Mortgage Bonds, 5.25% To 7.70%, Due 2031 To 2035 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.10%	6.10%
PacifiCorp [Member] | First Mortgage Bonds, 5.75% To 6.35%, Due 2036 To 2039 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.75%	5.75%
PacifiCorp [Member] | First Mortgage Bonds, 5.75% To 6.35%, Due 2036 To 2039 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.35%	6.35%
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		$ 27,476
Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		7,120
Eligible Property Subject To Lien Of Mortgages		$ 26,000
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 3.85% To 8.53%, Due Through 2021 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.85%	3.85%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 3.85% To 8.53%, Due Through 2021 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.53%	8.53%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 2.95% To 8.27%, Due 2022 To 2026 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		2.95%	2.95%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 2.95% To 8.27%, Due 2022 To 2026 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.27%	8.27%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 7.70%, Due 2031 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.70%	7.70%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 5.25% To 6.10%, Due 2034 to 2036 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.25%	5.25%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 5.25% To 6.10%, Due 2034 to 2036 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.10%	6.10%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 5.75% To 6.35%, Due 2037 To 2039 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.75%	5.75%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 5.75% To 6.35%, Due 2037 To 2039 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.35%	6.35%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 4.10%, Due 2042 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.10%	4.10%
Subsidiary Debt [Member] | PacifiCorp [Member] | Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.75%
Subsidiary Debt [Member] | PacifiCorp [Member] | Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		14.61%
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		$ 7,120
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | First Mortgage Bonds, 3.85% To 8.53%, Due Through 2021 [Member]
Debt Instrument [Line Items]
Par value		1,272
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | First Mortgage Bonds, 2.95% To 8.27%, Due 2022 To 2026 [Member]
Debt Instrument [Line Items]
Par value		1,829
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | First Mortgage Bonds, 7.70%, Due 2031 [Member]
Debt Instrument [Line Items]
Par value		300
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | First Mortgage Bonds, 5.25% To 6.10%, Due 2034 to 2036 [Member]
Debt Instrument [Line Items]
Par value		850
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | First Mortgage Bonds, 5.75% To 6.35%, Due 2037 To 2039 [Member]
Debt Instrument [Line Items]
Par value		2,150
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | First Mortgage Bonds, 4.10%, Due 2042 [Member]
Debt Instrument [Line Items]
Par value		300
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | Tax-exempt bond obligations, variable rate series, due 2018 to 2025 [Member]
Debt Instrument [Line Items]
Par value	[3]	108
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | Variable-rate tax-exempt obligation series due 2024 [Member]
Debt Instrument [Line Items]
Par value	[3],[4]	143
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | Variable-rate tax-exempt obligation series due 2024 to 2025 [Member]
Debt Instrument [Line Items]
Par value	[4]	50
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | Tax-exempt bond obligations, variable rate series, due 2017 to 2018 [Member]
Debt Instrument [Line Items]
Par value	[3]	91
Subsidiary Debt [Member] | PacifiCorp [Member] | PacifiCorp [Member] | Capital Lease Obligations, 8.75% To 14.61%, Due Through 2035 [Member]
Debt Instrument [Line Items]
Par value		$ 27
[1]	1)Supported by $255 million and $310 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2016 and 2015, respectively.
[2]	2)Secured by pledged first mortgage bonds registered to and held by the tax-exempt bond trustee generally with the same interest rates, maturity dates and redemption provisions as the tax-exempt bond obligations.
[3]	Supported by $255 million and $310 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2016 and 2015, respectively.
[4]	Secured by pledged first mortgage bonds registered to and held by the tax-exempt bond trustee generally with the same interest rates, maturity dates and redemption provisions as the tax-exempt bond obligations.

Subsidiary Debt Subsidiary D134

Subsidiary Debt Subsidiary Debt - PacifiCorp - Annual Payment on Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 1,006
Long-term Debt, Maturities, Repayments of Principal in Year Two	3,544
Long-term Debt, Maturities, Repayments of Principal in Year Three	2,099
Long-term Debt, Maturities, Repayments of Principal in Year Four	1,552
Long-term Debt, Maturities, Repayments of Principal in Year Five	823
Long-term Debt, Maturities, Repayments of Principal after Year Five	27,271
Par value	36,295
Long-term Debt	36,116	$ 37,972
PacifiCorp [Member]
Debt Instrument [Line Items]
Long-term Debt and Capital Lease Obligations, Repayments of Principal in Next Twelve Months	61
Long-term Debt and Capital Lease Obligations, Maturities, Repayments of Principal in Year Two	590
Long-term Debt and Capital Lease Obligations, Maturities, Repayments of Principal in Year Three	354
Long-term Debt and Capital Lease Obligations, Maturities, Repayments of Principal in Year Four	41
Long-term Debt and Capital Lease Obligations, Maturities, Repayments of Principal in Year Five	426
Long-term Debt and Capital Lease Obligations, Maturities, Repayments of Principal after Year Five	5,667
Total Long-term Debt Maturities and Capital Leases Future Minimum Payments	7,139
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	(41)
Capital Leases, Future Minimum Payments, Interest Included in Payments	(19)
Long-term Debt	7,052	7,114
Total long-term debt and capital lease obligations	7,079	$ 7,146
PacifiCorp [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	52
Long-term Debt, Maturities, Repayments of Principal in Year Two	586
Long-term Debt, Maturities, Repayments of Principal in Year Three	350
Long-term Debt, Maturities, Repayments of Principal in Year Four	38
Long-term Debt, Maturities, Repayments of Principal in Year Five	420
Long-term Debt, Maturities, Repayments of Principal after Year Five	5,647
Par value	7,093
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	(41)
Capital Leases, Future Minimum Payments, Interest Included in Payments	0
Long-term Debt	7,052
PacifiCorp [Member] | Capital Lease Obligations [Member]
Debt Instrument [Line Items]
Capital Leases, Future Minimum Payments Due, Next Twelve Months	9
Capital Leases, Future Minimum Payments Due in Two Years	4
Capital Leases, Future Minimum Payments Due in Three Years	4
Capital Leases, Future Minimum Payments Due in Four Years	3
Capital Leases, Future Minimum Payments Due in Five Years	6
Capital Leases, Future Minimum Payments Due Thereafter	20
Capital Leases, Future Minimum Payments Due	46
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	0
Capital Leases, Future Minimum Payments, Interest Included in Payments	(19)
Capital Lease Obligations	$ 27

Subsidiary Debt Subsidiary D135

Subsidiary Debt Subsidiary Debt - MEC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 01, 2016	Sep. 01, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value	$ 36,295
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	27,476
Other long-term debt	27,354			$ 27,214
MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Par value	4,332
Other long-term debt	4,301			4,271
Eligible Property Subject To Lien Of Mortgages	15,000
MidAmerican Energy Company [Member] | MEC First Mortgage Bonds, 2.40%, Due March 2019 [Member]
Debt Instrument [Line Items]
Par value	500
Other long-term debt	$ 499			$ 499
Debt Instrument, Interest Rate, Stated Percentage	2.40%			2.40%
MidAmerican Energy Company [Member] | MEC First Mortgage Bonds, 3.70%, Due September 2023 [Member]
Debt Instrument [Line Items]
Par value	$ 250
Other long-term debt	$ 248			$ 248
Debt Instrument, Interest Rate, Stated Percentage	3.70%			3.70%
MidAmerican Energy Company [Member] | MEC First Mortgage Bonds, 3.50%, Due October 2024 [Member]
Debt Instrument [Line Items]
Par value	$ 500
Other long-term debt	$ 501			$ 502
Debt Instrument, Interest Rate, Stated Percentage	3.50%			3.50%
MidAmerican Energy Company [Member] | MEC First Mortgage Bonds, 4.80%, Due September 2043 [Member]
Debt Instrument [Line Items]
Par value	$ 350
Other long-term debt	$ 345			$ 345
Debt Instrument, Interest Rate, Stated Percentage	4.80%			4.80%
MidAmerican Energy Company [Member] | MEC First Mortgage Bonds, 4.40%, Due October 2044 [Member]
Debt Instrument [Line Items]
Par value	$ 400
Other long-term debt	$ 394			$ 394
Debt Instrument, Interest Rate, Stated Percentage	4.40%			4.40%
MidAmerican Energy Company [Member] | MEC First Mortgage Bonds, 4.25%, Due May 2046 [Member]
Debt Instrument [Line Items]
Par value	$ 450
Other long-term debt	$ 445			$ 444
Debt Instrument, Interest Rate, Stated Percentage	4.25%			4.25%
MidAmerican Energy Company [Member] | MEC Notes, 5.95% Series, due 2017 [Member]
Debt Instrument [Line Items]
Par value	$ 250
Other long-term debt	$ 250			$ 250
Debt Instrument, Interest Rate, Stated Percentage	5.95%			5.95%
MidAmerican Energy Company [Member] | MEC Notes, 5.3% Series, due 2018 [Member]
Debt Instrument [Line Items]
Par value	$ 350
Other long-term debt	$ 350			$ 349
Debt Instrument, Interest Rate, Stated Percentage	5.30%			5.30%
MidAmerican Energy Company [Member] | MEC Notes, 6.75% Series, due 2031 [Member]
Debt Instrument [Line Items]
Par value	$ 400
Other long-term debt	$ 396			$ 395
Debt Instrument, Interest Rate, Stated Percentage	6.75%			6.75%
MidAmerican Energy Company [Member] | MEC Notes, 5.75% Series, due 2035 [Member]
Debt Instrument [Line Items]
Par value	$ 300
Other long-term debt	$ 298			$ 298
Debt Instrument, Interest Rate, Stated Percentage	5.75%			5.75%
MidAmerican Energy Company [Member] | MEC Notes, 5.8% Series, due 2036 [Member]
Debt Instrument [Line Items]
Par value	$ 350
Other long-term debt	$ 347			$ 347
Debt Instrument, Interest Rate, Stated Percentage	5.80%			5.80%
MidAmerican Energy Company [Member] | MEC Transmission Upgrade Obligations, 4.45% and 3.42% Due Through 2035 and 2036 [Member]
Debt Instrument [Line Items]
Par value	$ 10
Other long-term debt	$ 7			$ 4
MidAmerican Energy Company [Member] | Tax-exempt bond obligations, variable rate, due 2016-2046 [Member]
Debt Instrument [Line Items]
Variable interest rate	0.76%
MidAmerican Energy Company [Member] | MEC Transmission Upgrade Obligation, 4.449%, Due Through 2035 [Member]
Debt Instrument [Line Items]
Vendor Financing, Discount Rate Applied				4.45%
MidAmerican Energy Company [Member] | Variable Rate Tax Exempt Obligation Series Due 2016 [Member]
Debt Instrument [Line Items]
Par value	$ 0
Other long-term debt	0			$ 33
Debt Instrument, Repurchased Face Amount			$ 29
MidAmerican Energy Company [Member] | Variable Rate Tax Exempt Obligation Series Due 2017 [Member]
Debt Instrument [Line Items]
Par value	0
Other long-term debt	0			4
Debt Instrument, Repurchased Face Amount			4
MidAmerican Energy Company [Member] | Variable Rate Tax Exempt Obligation Series due 2023, issued 1993 [Member]
Debt Instrument [Line Items]
Par value	7
Other long-term debt	7			7
MidAmerican Energy Company [Member] | Variable Rate Tax Exempt Obligation Series Due 2023, issued in 2008 [Member]
Debt Instrument [Line Items]
Par value	57
Other long-term debt	57			57
MidAmerican Energy Company [Member] | Variable-rate tax-exempt obligation series due 2024 [Member]
Debt Instrument [Line Items]
Par value	35
Other long-term debt	35			35
MidAmerican Energy Company [Member] | Variable-rate tax-exempt obligation series, due 2025 [Member]
Debt Instrument [Line Items]
Par value	13
Other long-term debt	13			13
MidAmerican Energy Company [Member] | Variable-rate tax-exempt obligation series, due 2036 [Member]
Debt Instrument [Line Items]
Par value	33		$ 33
Other long-term debt	33			0
MidAmerican Energy Company [Member] | Variable-rate tax-exempt obligation series, due 2038 [Member]
Debt Instrument [Line Items]
Par value	45
Other long-term debt	45			45
MidAmerican Energy Company [Member] | Variable-rate tax-exempt obligation series, due 2046 [Member]
Debt Instrument [Line Items]
Par value	30	$ 30
Other long-term debt	29			0
MidAmerican Energy Company [Member] | Capital Lease Obligations, 4.16%, Due Through 2020 [Member]
Debt Instrument [Line Items]
Par value	2
Other long-term debt	$ 2			$ 2
Debt Instrument, Interest Rate, Stated Percentage	4.16%
MidAmerican Energy Company [Member] | Tax-exempt bond obligations, variable rate, due 2016-2038 [Member]
Debt Instrument [Line Items]
Variable interest rate				0.03%
Committed Common Equity Percentage To Regulators [Member] | MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Common equity to total capitalization percentage	42.00%
Committed Common Equity Percentage To Regulators Beyond Companies Control [Member] | MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Common equity to total capitalization percentage below which reasonable efforts to maintain agreed to percentage is not required	39.00%
Dividend Restriction For Common Equity Commitment [Member] | MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Amount Available for Dividend Distribution without Affecting Capital Adequacy Requirements	$ 2,000
Common Equity Level To Total Capitalization [Member] | MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Common Equity Level To Total Capitalization	53.00%
Maximum [Member] | MidAmerican Energy Company [Member] | MEC Transmission Upgrade Obligations, 4.45% and 3.42% Due Through 2035 and 2036 [Member]
Debt Instrument [Line Items]
Vendor Financing, Discount Rate Applied	4.45%
Minimum [Member] | MidAmerican Energy Company [Member] | MEC Transmission Upgrade Obligations, 4.45% and 3.42% Due Through 2035 and 2036 [Member]
Debt Instrument [Line Items]
Vendor Financing, Discount Rate Applied	3.42%
MidAmerican Funding [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	$ 4,657
Other long-term debt	4,592			$ 4,560
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	4,332
Other long-term debt	4,301			4,271
Eligible Property Subject To Lien Of Mortgages	15,000
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 2.40%, Due March 2019 [Member]
Debt Instrument [Line Items]
Par value	500
Other long-term debt	$ 499			$ 499
Debt Instrument, Interest Rate, Stated Percentage	2.40%			2.40%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 3.70%, Due September 2023 [Member]
Debt Instrument [Line Items]
Par value	$ 250
Other long-term debt	$ 248			$ 248
Debt Instrument, Interest Rate, Stated Percentage	3.70%			3.70%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 3.50%, Due October 2024 [Member]
Debt Instrument [Line Items]
Par value	$ 500
Other long-term debt	$ 501			$ 502
Debt Instrument, Interest Rate, Stated Percentage	3.50%			3.50%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 4.80%, Due September 2043 [Member]
Debt Instrument [Line Items]
Par value	$ 350
Other long-term debt	$ 345			$ 345
Debt Instrument, Interest Rate, Stated Percentage	4.80%			4.80%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 4.40%, Due October 2044 [Member]
Debt Instrument [Line Items]
Par value	$ 400
Other long-term debt	$ 394			$ 394
Debt Instrument, Interest Rate, Stated Percentage	4.40%			4.40%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 4.25%, Due May 2046 [Member]
Debt Instrument [Line Items]
Par value	$ 450
Other long-term debt	$ 445			$ 444
Debt Instrument, Interest Rate, Stated Percentage	4.25%			0.00%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC Notes, 5.95% Series, due 2017 [Member]
Debt Instrument [Line Items]
Par value	$ 250
Other long-term debt	$ 250			$ 250
Debt Instrument, Interest Rate, Stated Percentage	5.95%			5.95%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC Notes, 5.3% Series, due 2018 [Member]
Debt Instrument [Line Items]
Par value	$ 350
Other long-term debt	$ 350			$ 349
Debt Instrument, Interest Rate, Stated Percentage	5.30%			5.30%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC Notes, 6.75% Series, due 2031 [Member]
Debt Instrument [Line Items]
Par value	$ 400
Other long-term debt	$ 396			$ 395
Debt Instrument, Interest Rate, Stated Percentage	6.75%			6.75%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC Notes, 5.75% Series, due 2035 [Member]
Debt Instrument [Line Items]
Par value	$ 300
Other long-term debt	$ 298			$ 298
Debt Instrument, Interest Rate, Stated Percentage	5.75%			5.75%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC Notes, 5.8% Series, due 2036 [Member]
Debt Instrument [Line Items]
Par value	$ 350
Other long-term debt	$ 347			$ 347
Debt Instrument, Interest Rate, Stated Percentage	5.80%			5.80%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC Transmission Upgrade Obligations, 4.45% and 3.42% Due Through 2035 and 2036 [Member]
Debt Instrument [Line Items]
Par value	$ 10
Other long-term debt	7			$ 4
Vendor Financing, Discount Rate Applied				4.45%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | Tax-exempt bond obligations, variable rate, due 2016-2046 [Member]
Debt Instrument [Line Items]
Par value	220
Other long-term debt	$ 219			$ 194
Variable interest rate	0.76%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | Capital Lease Obligations, 4.16%, Due Through 2020 [Member]
Debt Instrument [Line Items]
Par value	$ 2
Other long-term debt	$ 2			$ 2
Vendor Financing, Discount Rate Applied	4.16%			4.16%
MidAmerican Funding [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | Tax-exempt bond obligations, variable rate, due 2016-2038 [Member]
Debt Instrument [Line Items]
Variable interest rate				0.03%
MidAmerican Funding [Member] | Maximum [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC Transmission Upgrade Obligations, 4.45% and 3.42% Due Through 2035 and 2036 [Member]
Debt Instrument [Line Items]
Vendor Financing, Discount Rate Applied	4.45%
MidAmerican Funding [Member] | Minimum [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC Transmission Upgrade Obligations, 4.45% and 3.42% Due Through 2035 and 2036 [Member]
Debt Instrument [Line Items]
Vendor Financing, Discount Rate Applied	3.42%

Subsidiary Debt Subsidiary D136

Subsidiary Debt Subsidiary Debt - MEC - Maturity Schedule (Details) $ in Millions	Dec. 31, 2016USD ($)
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 1,006
Long-term Debt, Maturities, Repayments of Principal in Year Two	3,544
Long-term Debt, Maturities, Repayments of Principal in Year Three	2,099
Long-term Debt, Maturities, Repayments of Principal in Year Four	1,552
Long-term Debt, Maturities, Repayments of Principal in Year Five	823
Long-term Debt, Maturities, Repayments of Principal after Year Five	27,271
MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	251
Long-term Debt, Maturities, Repayments of Principal in Year Two	351
Long-term Debt, Maturities, Repayments of Principal in Year Three	500
Long-term Debt, Maturities, Repayments of Principal in Year Four	2
Long-term Debt, Maturities, Repayments of Principal in Year Five	1
Long-term Debt, Maturities, Repayments of Principal after Year Five	$ 3,227

Subsidiary Debt - MidAmerican F

Subsidiary Debt - MidAmerican Funding (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value		$ 36,295
Equity Restrictions		15,100
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		27,476
Other long-term debt		27,354	$ 27,214
BHE Renewables [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		3,716
Other long-term debt		3,674	3,356
BHE Renewables [Member] | Subsidiary Debt [Member] | Solar Star Funding, LLC Series A Senior Secured Notes, 3.950%, due June 2035 [Member]
Debt Instrument [Line Items]
Par value	[1]	316
Other long-term debt	[1]	$ 311	$ 321
Debt Instrument, Interest Rate, Stated Percentage		3.95%	3.95%
BHE Renewables [Member] | Subsidiary Debt [Member] | Solar Star Funding, LLC Series A Senior Secured Notes, 5.375%, due June 2016 through June 2035 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 977
Other long-term debt	[1]	$ 966	$ 988
Debt Instrument, Interest Rate, Stated Percentage		5.375%	5.375%
BHE Renewables [Member] | Subsidiary Debt [Member] | Marshall Wind term loan, variable interest rate, due 2026 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 93
Other long-term debt		$ 90	$ 0
Debt Instrument, Interest Rate, Stated Percentage		3.212%	0.00%
BHE Renewables [Member] | Subsidiary Debt [Member] | Pinyon Pines I and II Term Loans, due 2019 [Member]
Debt Instrument [Line Items]
Par value	[1],[2]	$ 356
Other long-term debt	[1],[2]	$ 355	$ 378
Debt Instrument, Interest Rate, Stated Percentage		3.55%	3.55%
Variable interest rate		2.62%	2.23%
BHE Renewables [Member] | Subsidiary Debt [Member] | Wailuku Special Purpose Revenue Bonds, 0.09% due 2021 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 7
Other long-term debt	[1]	$ 7	$ 8
Debt Instrument, Interest Rate, Stated Percentage		0.90%	0.90%
BHE Renewables [Member] | Subsidiary Debt [Member] | Grande Prairie Wind, Senior Notes, 3.860%, due 2037 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 419
Other long-term debt		414	$ 0
MidAmerican Funding [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		4,657
Other long-term debt		4,592	4,560
NV Energy, Inc. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		4,569
Other long-term debt		4,582	4,860
AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[3]	3,608
Other long-term debt		3,592	2,911
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2015-1 Notes, 4.090%, due 2045 [Member]
Debt Instrument [Line Items]
Par value	[3]	260
Other long-term debt		$ 259	$ 251
Debt Instrument, Interest Rate, Stated Percentage		4.09%	4.09%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2014-1 Notes, 3.399%, due 2024 [Member]
Debt Instrument [Line Items]
Par value	[3]	$ 260
Other long-term debt		$ 260	$ 252
Debt Instrument, Interest Rate, Stated Percentage		3.399%	3.399%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2014-2 Notes, 4.274%, due 2064 [Member]
Debt Instrument [Line Items]
Par value	[3]	$ 97
Other long-term debt		$ 97	$ 93
Debt Instrument, Interest Rate, Stated Percentage		4.274%	4.274%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Construction Loan, 4.950%, due 2021 [Member]
Debt Instrument [Line Items]
Par value	[3]	$ 13
Other long-term debt		$ 13	$ 0
Debt Instrument, Interest Rate, Stated Percentage		4.95%	0.00%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2016-1 Notes, 2.747%, due 2026 [Member]
Debt Instrument [Line Items]
Par value	[3]	$ 260
Other long-term debt		$ 259	$ 0
Debt Instrument, Interest Rate, Stated Percentage		2.747%	0.00%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2016-2 Notes, 3.717%, due 2046 [Member]
Debt Instrument [Line Items]
Par value	[3]	$ 335
Other long-term debt		$ 333	$ 0
Debt Instrument, Interest Rate, Stated Percentage		3.717%	0.00%
Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value		$ 1,154
Eligible Property Subject To Lien Of Mortgages		$ 3,800
Sierra Pacific Power Company [Member] | Mortgage securities, 6.000%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.00%	6.00%
Sierra Pacific Power Company [Member] | Mortgage securities, 2.600%, Series U due 2026 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		2.60%
Sierra Pacific Power Company [Member] | Mortgage securities, 3.375%, Series T due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.375%	3.375%
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006C due 2036 [Member]
Debt Instrument [Line Items]
Par value		$ 0
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006B due 2036 [Member]
Debt Instrument [Line Items]
Par value		0
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2031 [Member]
Debt Instrument [Line Items]
Par value		0
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Pollution Control Refunding Revenue Bonds, 1.250%, Series 2016A, due 2029 [Member]
Debt Instrument [Line Items]
Par value		20
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Mortgage securities, 6.000%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Par value		0
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Mortgage securities, 2.600%, Series U due 2026 [Member]
Debt Instrument [Line Items]
Par value		400
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Mortgage securities, 3.375%, Series T due 2023 [Member]
Debt Instrument [Line Items]
Par value		250
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Gas facilities refunding revenue bonds, 1.500%, series 2016A, due 2031 [Member]
Debt Instrument [Line Items]
Par value		58
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Gas and water facilities refunding revenue bonds, 3.000% series 2016B, due 2036 [Member]
Debt Instrument [Line Items]
Par value		60
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Water facilities refunding revenue bonds, series 2016C, due 2036 [Member]
Debt Instrument [Line Items]
Par value		30
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Water facilities refunding revenue bonds, series 2016D, due 2036 [Member]
Debt Instrument [Line Items]
Par value		25
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Water facilities refunding revenue bonds, series 2016E, due 2036 [Member]
Debt Instrument [Line Items]
Par value		25
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		1,154
Other long-term debt		1,153	$ 1,202
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006C due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt		0	80
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006B due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt		0	74
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2031 [Member]
Debt Instrument [Line Items]
Other long-term debt		0	58
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Pollution Control Refunding Revenue Bonds, 1.250%, Series 2016A, due 2029 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 20	$ 0
Debt Instrument, Interest Rate, Stated Percentage		1.25%	1.25%
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Mortgage securities, 6.000%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 0	$ 450
Debt Instrument, Interest Rate, Stated Percentage		6.00%	6.00%
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Mortgage securities, 2.600%, Series U due 2026 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 395	$ 0
Debt Instrument, Interest Rate, Stated Percentage			2.60%
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Mortgage securities, 3.375%, Series T due 2023 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 248	$ 248
Debt Instrument, Interest Rate, Stated Percentage		3.375%	3.375%
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Gas facilities refunding revenue bonds, 1.500%, series 2016A, due 2031 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 58	$ 0
Debt Instrument, Interest Rate, Stated Percentage		1.50%	1.50%
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Gas and water facilities refunding revenue bonds, 3.000% series 2016B, due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 64	$ 0
Debt Instrument, Interest Rate, Stated Percentage		3.00%	3.00%
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016C, due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 29	$ 0
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016D, due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt		25	0
Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016E, due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt		25	0
MidAmerican Funding, LLC and Subsidiaries [Domain]
Debt Instrument [Line Items]
Equity Restrictions		3,100
MidAmerican Funding LLC [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | Senior Notes, 6.927%, due 2029 [Member]
Debt Instrument [Line Items]
Par value		325
Other long-term debt		$ 291	$ 289
Debt Instrument, Interest Rate, Stated Percentage		6.927%	6.927%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		$ 4,332
Other long-term debt		4,301	$ 4,271
Eligible Property Subject To Lien Of Mortgages		15,000
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | Tax-exempt bond obligations, variable rate, due 2016-2046 [Member]
Debt Instrument [Line Items]
Par value		220
Other long-term debt		$ 219	$ 194
Variable interest rate		0.76%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | Tax-exempt bond obligations, variable rate, due 2016-2038 [Member]
Debt Instrument [Line Items]
Variable interest rate			0.03%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 2.40%, Due March 2019 [Member]
Debt Instrument [Line Items]
Par value		$ 500
Other long-term debt		$ 499	$ 499
Debt Instrument, Interest Rate, Stated Percentage		2.40%	2.40%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 3.70%, Due September 2023 [Member]
Debt Instrument [Line Items]
Par value		$ 250
Other long-term debt		$ 248	$ 248
Debt Instrument, Interest Rate, Stated Percentage		3.70%	3.70%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 3.50%, due 2024 [Member]
Debt Instrument [Line Items]
Par value		$ 500
Other long-term debt		$ 501	$ 502
Debt Instrument, Interest Rate, Stated Percentage		3.50%	3.50%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 4.80%, Due September 2043 [Member]
Debt Instrument [Line Items]
Par value		$ 350
Other long-term debt		$ 345	$ 345
Debt Instrument, Interest Rate, Stated Percentage		4.80%	4.80%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 4.40%, Due October 2044 [Member]
Debt Instrument [Line Items]
Par value		$ 400
Other long-term debt		$ 394	$ 394
Debt Instrument, Interest Rate, Stated Percentage		4.40%	4.40%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 4.25%, Due May 2046 [Member]
Debt Instrument [Line Items]
Par value		$ 450
Other long-term debt		$ 445	$ 444
Debt Instrument, Interest Rate, Stated Percentage		4.25%	0.00%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC Notes, 5.95% Series, due 2017 [Member]
Debt Instrument [Line Items]
Par value		$ 250
Other long-term debt		$ 250	$ 250
Debt Instrument, Interest Rate, Stated Percentage		5.95%	5.95%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC Notes, 5.3% Series, due 2018 [Member]
Debt Instrument [Line Items]
Par value		$ 350
Other long-term debt		$ 350	$ 349
Debt Instrument, Interest Rate, Stated Percentage		5.30%	5.30%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC Notes, 6.75% Series, due 2031 [Member]
Debt Instrument [Line Items]
Par value		$ 400
Other long-term debt		$ 396	$ 395
Debt Instrument, Interest Rate, Stated Percentage		6.75%	6.75%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC Notes, 5.75% Series, due 2035 [Member]
Debt Instrument [Line Items]
Par value		$ 300
Other long-term debt		$ 298	$ 298
Debt Instrument, Interest Rate, Stated Percentage		5.75%	5.75%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC Notes, 5.8% Series, due 2036 [Member]
Debt Instrument [Line Items]
Par value		$ 350
Other long-term debt		$ 347	$ 347
Debt Instrument, Interest Rate, Stated Percentage		5.80%	5.80%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC Transmission Upgrade Obligations, 4.45% and 3.42% Due Through 2035 and 2036 [Member]
Debt Instrument [Line Items]
Par value		$ 10
Other long-term debt		7	$ 4
Vendor Financing, Discount Rate Applied			4.45%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | Capital Lease Obligations, 4.16%, Due Through 2020 [Member]
Debt Instrument [Line Items]
Par value		2
Other long-term debt		$ 2	$ 2
Vendor Financing, Discount Rate Applied		4.16%	4.16%
MidAmerican Funding LLC [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain] | Senior Notes, 6.927%, due 2029 [Member]
Debt Instrument [Line Items]
Par value		$ 325
Other long-term debt		$ 326	$ 326
Minimum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006C due 2036 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.788%	0.733%
Minimum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006B due 2036 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.788%	0.733%
Minimum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2031 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.788%	0.733%
Minimum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016C, due 2036 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.788%	0.733%
Minimum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016D, due 2036 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.788%	0.733%
Minimum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016E, due 2036 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.788%	0.733%
Minimum [Member] | MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC Transmission Upgrade Obligations, 4.45% and 3.42% Due Through 2035 and 2036 [Member]
Debt Instrument [Line Items]
Vendor Financing, Discount Rate Applied		3.42%
Maximum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006C due 2036 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.80%	1.054%
Maximum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006B due 2036 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.80%	1.054%
Maximum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2031 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.80%	1.054%
Maximum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016C, due 2036 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.80%	1.054%
Maximum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016D, due 2036 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.80%	1.054%
Maximum [Member] | Sierra Pacific Power Company [Member] | NV Energy, Inc. [Member] | Subsidiary Debt [Member] | Water facilities refunding revenue bonds, series 2016E, due 2036 [Member]
Debt Instrument [Line Items]
Variable interest rate		0.80%	1.054%
Maximum [Member] | MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC Transmission Upgrade Obligations, 4.45% and 3.42% Due Through 2035 and 2036 [Member]
Debt Instrument [Line Items]
Vendor Financing, Discount Rate Applied		4.45%
[1]	Amortizes quarterly or semiannually.
[2]	The term loans have variable interest rates based on LIBOR plus a margin that varies during the terms of the agreements. The Company has entered into interest rate swaps that fix the interest rate on 75% of the Pinyon Pines outstanding debt and 100% of the TX Jumbo Road and Marshall Wind outstanding debt. The variable interest rate as of December 31, 2016 and 2015 was 2.62% and 2.23%, respectively, while the fixed interest rates ranged from 3.21% to 3.63% as of December 31, 2016, and 3.55% to 3.63% as of December 31, 2015.
[3]	(1)The par values for these debt instruments are denominated in Canadian dollars.

Subsidiary Debt Subsidiary D138

Subsidiary Debt Subsidiary Debt - NPC - Capital and Financial Lease Obligations (Details) - USD ($) $ in Millions	Jan. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value		$ 36,295
Nevada Power Company [Member]
Debt Instrument [Line Items]
Par value		3,100
Total Long-term Debt and Capital and Financial Lease Obligations		3,066	$ 3,285
Long-term Debt and Capital and Financial Lease Obligations, Current		17	225
Long-term Debt and Capital and Financial Lease Obligations		$ 3,049	$ 3,060
Nevada Power Company [Member] | Mortgage Securities, 5.950%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.95%	5.95%
Nevada Power Company [Member] | Mortgage Securities, 6.500%, Series O due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.50%	6.50%
Nevada Power Company [Member] | Mortgage Securities, 6.500%, Series S due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.50%	6.50%
Nevada Power Company [Member] | Mortgage Securities, 7.125%, Series V due 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.125%	7.125%
Nevada Power Company [Member] | Mortgage Securities, 6.650%, Series N due 2036 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.65%	6.65%
Nevada Power Company [Member] | Mortgage Securities, 6.750%, Series R due 2037 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.75%	6.75%
Nevada Power Company [Member] | Mortgage Securities, 5.375%, Series X due 2040 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.375%	5.375%
Nevada Power Company [Member] | Mortgage Securities, 5.450%, Series Y due 2041 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.45%	5.45%
Minimum [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		1.89%	0.672%
Minimum [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		1.89%	0.672%
Minimum [Member] | Nevada Power Company [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		2.75%	2.75%
Maximum [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		1.928%	1.055%
Maximum [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		1.928%	1.055%
Maximum [Member] | Nevada Power Company [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		11.60%	11.60%
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		$ 27,476
Other long-term debt		27,354	$ 27,214
NV Energy [Member] | Nevada Power Company [Member] | Mortgage Securities, 5.950%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Par value		0
NV Energy [Member] | Nevada Power Company [Member] | Mortgage Securities, 6.500%, Series O due 2018 [Member]
Debt Instrument [Line Items]
Par value		324
NV Energy [Member] | Nevada Power Company [Member] | Mortgage Securities, 6.500%, Series S due 2018 [Member]
Debt Instrument [Line Items]
Par value		499
NV Energy [Member] | Nevada Power Company [Member] | Mortgage Securities, 7.125%, Series V due 2019 [Member]
Debt Instrument [Line Items]
Par value		500
NV Energy [Member] | Nevada Power Company [Member] | Mortgage Securities, 6.650%, Series N due 2036 [Member]
Debt Instrument [Line Items]
Par value		367
NV Energy [Member] | Nevada Power Company [Member] | Mortgage Securities, 6.750%, Series R due 2037 [Member]
Debt Instrument [Line Items]
Par value		349
NV Energy [Member] | Nevada Power Company [Member] | Mortgage Securities, 5.375%, Series X due 2040 [Member]
Debt Instrument [Line Items]
Par value		250
NV Energy [Member] | Nevada Power Company [Member] | Mortgage Securities, 5.450%, Series Y due 2041 [Member]
Debt Instrument [Line Items]
Par value		250
NV Energy [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Par value		38
NV Energy [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Par value		38
NV Energy [Member] | Nevada Power Company [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Par value		485
NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		4,569
Other long-term debt		4,582	4,860
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member]
Debt Instrument [Line Items]
Par value		3,100
Other long-term debt		3,066	3,285
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Mortgage Securities, 5.950%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 0	$ 210
Debt Instrument, Interest Rate, Stated Percentage		5.95%	5.95%
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Mortgage Securities, 6.500%, Series O due 2018 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 324	$ 323
Debt Instrument, Interest Rate, Stated Percentage		6.50%	6.50%
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Mortgage Securities, 6.500%, Series S due 2018 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 498	$ 498
Debt Instrument, Interest Rate, Stated Percentage		6.50%	6.50%
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Mortgage Securities, 7.125%, Series V due 2019 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 499	$ 499
Debt Instrument, Interest Rate, Stated Percentage		7.125%	7.125%
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Mortgage Securities, 6.650%, Series N due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 357	$ 356
Debt Instrument, Interest Rate, Stated Percentage		6.65%	6.65%
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Mortgage Securities, 6.750%, Series R due 2037 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 345	$ 345
Debt Instrument, Interest Rate, Stated Percentage		6.75%	6.75%
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Mortgage Securities, 5.375%, Series X due 2040 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 247	$ 247
Debt Instrument, Interest Rate, Stated Percentage		5.375%	5.375%
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Mortgage Securities, 5.450%, Series Y due 2041 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 236	$ 235
Debt Instrument, Interest Rate, Stated Percentage		5.45%	5.45%
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 38	$ 38
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Other long-term debt		37	37
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Other long-term debt		$ 485	$ 497
NV Energy [Member] | Subsidiary Debt [Member] | Minimum [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		1.89%	0.672%
NV Energy [Member] | Subsidiary Debt [Member] | Minimum [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		1.89%	0.672%
NV Energy [Member] | Subsidiary Debt [Member] | Minimum [Member] | Nevada Power Company [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		2.75%	2.75%
NV Energy [Member] | Subsidiary Debt [Member] | Maximum [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		1.928%	1.055%
NV Energy [Member] | Subsidiary Debt [Member] | Maximum [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		1.928%	1.055%
NV Energy [Member] | Subsidiary Debt [Member] | Maximum [Member] | Nevada Power Company [Member] | Capital lease obligations, 2.75% to 11.60%, due through 2054 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		11.60%	11.60%
Equipment [Member] | Nevada Power Company [Member]
Debt Instrument [Line Items]
Capital Leased Assets, Gross			$ 1
Subsequent Event [Member] | NV Energy [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2032 [Member]
Debt Instrument [Line Items]
Debt Instrument, Repurchase Amount	$ 38
Subsequent Event [Member] | NV Energy [Member] | Nevada Power Company [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006 due 2036 [Member]
Debt Instrument [Line Items]
Debt Instrument, Repurchase Amount	$ 38

Subsidiary Debt Subsidiary D139

Subsidiary Debt Subsidiary Debt - NPC - Annual Payment on Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 1,006
Long-term Debt, Maturities, Repayments of Principal in Year Two	3,544
Long-term Debt, Maturities, Repayments of Principal in Year Three	2,099
Long-term Debt, Maturities, Repayments of Principal in Year Four	1,552
Long-term Debt, Maturities, Repayments of Principal in Year Five	823
Long-term Debt, Maturities, Repayments of Principal after Year Five	27,271
Par value	36,295
Long-term Debt	36,116	$ 37,972
Nevada Power Company [Member]
Debt Instrument [Line Items]
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Next Twelve Months	75
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Two	897
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Three	576
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Four	75
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Five	79
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal Thereafter	2,123
Par value	3,100
Total Long-term Debt Maturities and Capital and Financial Leases Future Minimum Payments	3,825
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	34
Executory costs	111
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	614
Long-term Debt	2,581	$ 2,788
Long-term Debt and Capital and Financial Lease Obligations, Including Current Maturities	3,066
Nevada Power Company [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	0
Long-term Debt, Maturities, Repayments of Principal in Year Two	823
Long-term Debt, Maturities, Repayments of Principal in Year Three	500
Long-term Debt, Maturities, Repayments of Principal in Year Four	0
Long-term Debt, Maturities, Repayments of Principal in Year Five	0
Long-term Debt, Maturities, Repayments of Principal after Year Five	1,292
Par value	2,615
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	34
Executory costs	0
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	0
Long-term Debt	2,581
Nevada Power Company [Member] | Capital and Financial Lease Obligations [Member]
Debt Instrument [Line Items]
Capital and Financial Leases, Future Minimum Payments Due, Next Twelve Months	75
Capital and Financial Leases, Future Minimum Payments Due in Two Years	74
Capital and Financial Leases, Future Minimum Payments Due in Three Years	76
Capital and Financial Leases, Future Minimum Payments Due in Four Years	75
Capital and Financial Leases, Future Minimum Payments Due in Five Years	79
Capital and Financial Leases, Future Minimum Payments Due Thereafter	831
Capital and Financial Leases, Future Minimum Payments Due	1,210
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	0
Executory costs	111
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	614
Capital and Financial Lease Obligations	$ 485

Subsidiary Debt Subsidiary D140

Subsidiary Debt Subsidiary Debt - NPC - (Details) - Nevada Power Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)option	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Eligible Property Subject To Lien Of Mortgages	$ 8,900
Building [Member]
Debt Instrument [Line Items]
Terms Of Capital Lease	30 years
Renewal Options Under Capital Lease, Number | option	5
Number Of Years In Renewal Period	5 years
Number Of Renewal Options Exercised Under Capital Lease | option	3
Number Of Additional Renewal Options Under Capital Lease | option	2
Extended Additional Term Of Capital Lease	10 years
Capital Leased Assets, Gross	$ 25	$ 27
Land and Building [Member]
Debt Instrument [Line Items]
Terms Of Capital Lease	20 years
Renewal Options Under Capital Lease, Number | option	3
Number Of Years In Renewal Period	10 years
Capital Leased Assets, Gross	$ 7
Long-Term Energy Purchase Contracts [Member]
Debt Instrument [Line Items]
Number Of Years In Renewal Period	30 years
Capital Leased Assets, Gross	$ 38	40
Equipment [Member]
Debt Instrument [Line Items]
Terms Of Capital Lease	7 years
Capital Leased Assets, Gross		1
ON Line Transmission Line [Member]
Debt Instrument [Line Items]
Terms Of Capital Lease	41 years
Capital Leased Assets, Gross	$ 402	$ 410
Utilities Aggregate Share Transmission Line Project	25.00%
Remaining Share Transmission Line Project	75.00%
Nevada Power Company [Member] | ON Line Transmission Line [Member]
Debt Instrument [Line Items]
Utilities Aggregate Share Transmission Line Project	95.00%
Sierra Pacific Power Company [Member] | ON Line Transmission Line [Member]
Debt Instrument [Line Items]
Utilities Aggregate Share Transmission Line Project	5.00%

Subsidiary Debt Subsidiary D141

Subsidiary Debt Subsidiary Debt - SPPC - Capital and Financial Lease Obligations (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Par value	$ 36,295
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	27,476
Other long-term debt	27,354	$ 27,214
Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	1,154
Total Long-term Debt and Capital and Financial Lease Obligations	1,153	1,202
Long-term Debt and Capital and Financial Lease Obligations, Current	1	453
Long-term Debt and Capital and Financial Lease Obligations	1,152	749
Long-term Debt and Capital and Financial Lease Obligations, Including Current Maturities	1,153	1,202
NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	4,569
Other long-term debt	4,582	4,860
NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	1,154
Other long-term debt	$ 1,153	$ 1,202
Mortgage securities, 6.000%, Series M due 2016 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.00%	6.00%
Mortgage securities, 6.000%, Series M due 2016 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 0
Mortgage securities, 6.000%, Series M due 2016 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 0	$ 450
Debt Instrument, Interest Rate, Stated Percentage	6.00%	6.00%
Mortgage securities, 3.375%, Series T due 2023 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.375%	3.375%
Mortgage securities, 3.375%, Series T due 2023 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 250
Mortgage securities, 3.375%, Series T due 2023 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 248	$ 248
Debt Instrument, Interest Rate, Stated Percentage	3.375%	3.375%
Mortgage securities, 2.600%, Series U due 2026 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.60%
Mortgage securities, 2.600%, Series U due 2026 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 400
Mortgage securities, 2.600%, Series U due 2026 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 395	$ 0
Debt Instrument, Interest Rate, Stated Percentage		2.60%
Mortgage securities, 6.750%, Series P due 2037 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.75%	6.75%
Mortgage securities, 6.750%, Series P due 2037 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 252
Mortgage securities, 6.750%, Series P due 2037 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 255	$ 255
Debt Instrument, Interest Rate, Stated Percentage	6.75%	6.75%
Pollution Control Refunding Revenue Bonds, 1.250%, Series 2016A, due 2029 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 20
Pollution Control Refunding Revenue Bonds, 1.250%, Series 2016A, due 2029 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 20	$ 0
Debt Instrument, Interest Rate, Stated Percentage	1.25%	1.25%
Gas facilities refunding revenue bonds, 1.500%, series 2016A, due 2031 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 58
Gas facilities refunding revenue bonds, 1.500%, series 2016A, due 2031 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 58	$ 0
Debt Instrument, Interest Rate, Stated Percentage	1.50%	1.50%
Gas and water facilities refunding revenue bonds, 3.000% series 2016B, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 60
Gas and water facilities refunding revenue bonds, 3.000% series 2016B, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 64	$ 0
Debt Instrument, Interest Rate, Stated Percentage	3.00%	3.00%
Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2031 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 0
Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2031 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	0	$ 58
Pollution Control Revenue Bonds, Variable-Rate, Series 2006B due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	0
Pollution Control Revenue Bonds, Variable-Rate, Series 2006B due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	0	74
Pollution Control Revenue Bonds, Variable-Rate, Series 2006C due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	0
Pollution Control Revenue Bonds, Variable-Rate, Series 2006C due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	0	80
Water facilities refunding revenue bonds, series 2016C, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	30
Water facilities refunding revenue bonds, series 2016C, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	29	0
Water facilities refunding revenue bonds, series 2016D, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	25
Water facilities refunding revenue bonds, series 2016D, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	25	0
Water facilities refunding revenue bonds, series 2016E, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	25
Water facilities refunding revenue bonds, series 2016E, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	25	0
Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value	34
Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 34	$ 37
Minimum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2031 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.788%	0.733%
Minimum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006B due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.788%	0.733%
Minimum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006C due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.788%	0.733%
Minimum [Member] | Water facilities refunding revenue bonds, series 2016C, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.788%	0.733%
Minimum [Member] | Water facilities refunding revenue bonds, series 2016D, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.788%	0.733%
Minimum [Member] | Water facilities refunding revenue bonds, series 2016E, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.788%	0.733%
Minimum [Member] | Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Variable interest rate	2.70%	2.70%
Minimum [Member] | Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	2.70%	2.70%
Maximum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2031 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.80%	1.054%
Maximum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006B due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.80%	1.054%
Maximum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006C due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.80%	1.054%
Maximum [Member] | Water facilities refunding revenue bonds, series 2016C, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.80%	1.054%
Maximum [Member] | Water facilities refunding revenue bonds, series 2016D, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.80%	1.054%
Maximum [Member] | Water facilities refunding revenue bonds, series 2016E, due 2036 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	0.80%	1.054%
Maximum [Member] | Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Variable interest rate	10.13%	8.548%
Maximum [Member] | Capital and financial lease obligations, 2.700% to 8.548%, due through 2054 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Variable interest rate	10.13%	8.548%
Equipment [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Capital Leased Assets, Gross	$ 3	$ 3

Subsidiary Debt Subsidiary D142

Subsidiary Debt Subsidiary Debt - SPPC - Annual Payment on Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 1,006
Long-term Debt, Maturities, Repayments of Principal in Year Two	3,544
Long-term Debt, Maturities, Repayments of Principal in Year Three	2,099
Long-term Debt, Maturities, Repayments of Principal in Year Four	1,552
Long-term Debt, Maturities, Repayments of Principal in Year Five	823
Long-term Debt, Maturities, Repayments of Principal after Year Five	27,271
Par value	36,295
Long-term Debt	36,116	$ 37,972
Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Next Twelve Months	4
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Two	4
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Three	4
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Four	4
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Five	3
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal Thereafter	1,170
Par value	1,154
Total Long-term Debt Maturities and Capital and Financial Leases Future Minimum Payments	1,189
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	(1)
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	(35)
Long-term Debt	1,119	1,165
Long-term Debt and Capital and Financial Lease Obligations, Including Current Maturities	1,153	$ 1,202
Eligible Property Subject To Lien Of Mortgages	3,800
Sierra Pacific Power Company [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	0
Long-term Debt, Maturities, Repayments of Principal in Year Two	0
Long-term Debt, Maturities, Repayments of Principal in Year Three	0
Long-term Debt, Maturities, Repayments of Principal in Year Four	0
Long-term Debt, Maturities, Repayments of Principal in Year Five	0
Long-term Debt, Maturities, Repayments of Principal after Year Five	1,120
Par value	1,120
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	(1)
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	0
Long-term Debt	1,119
Sierra Pacific Power Company [Member] | Capital and Financial Lease Obligations [Member]
Debt Instrument [Line Items]
Capital and Financial Leases, Future Minimum Payments Due, Next Twelve Months	4
Capital and Financial Leases, Future Minimum Payments Due in Two Years	4
Capital and Financial Leases, Future Minimum Payments Due in Three Years	4
Capital and Financial Leases, Future Minimum Payments Due in Four Years	4
Capital and Financial Leases, Future Minimum Payments Due in Five Years	3
Capital and Financial Leases, Future Minimum Payments Due Thereafter	50
Capital and Financial Leases, Future Minimum Payments Due	69
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	0
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	(35)
Capital and Financial Lease Obligations	$ 34

Subsidiary Debt Subsidiary D143

Subsidiary Debt Subsidiary Debt - SPPC (Details) - Sierra Pacific Power Company [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Equipment [Member]
Debt Instrument [Line Items]
Terms Of Capital Lease	7 years
Capital Leased Assets, Gross	$ 3	$ 3
ON Line Transmission Line [Member]
Debt Instrument [Line Items]
Terms Of Capital Lease	41 years
Capital Leased Assets, Gross	$ 21	22
Utilities Aggregate Share Transmission Line Project	25.00%
Remaining Share Transmission Line Project	75.00%
Solar Generating Facility [Member]
Debt Instrument [Line Items]
Terms Of Capital Lease	20 years
Capital Leased Assets, Gross	$ 10	$ 12
Sierra Pacific Power Company [Member] | ON Line Transmission Line [Member]
Debt Instrument [Line Items]
Utilities Aggregate Share Transmission Line Project	5.00%
Nevada Power Company [Member] | ON Line Transmission Line [Member]
Debt Instrument [Line Items]
Utilities Aggregate Share Transmission Line Project	95.00%

Risk Management and Hedging 144

Risk Management and Hedging Activities - Balance Sheet Location (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		$ (77)	$ (237)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		74	103
Derivative Assets (Liabilities), at Fair Value, Net		(3)	(134)
Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		48	28
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		48	28
Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		94	75
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		94	75
Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(60)	(145)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		13	40
Derivative Assets (Liabilities), at Fair Value, Net		(47)	(105)
Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(159)	(195)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		61	63
Derivative Assets (Liabilities), at Fair Value, Net		(98)	(132)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(66)	(188)
Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		47	28
Not Designated as Hedging Instrument [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		86	72
Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(45)	(109)
Not Designated as Hedging Instrument [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(154)	(179)
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(11)	(49)
Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		1	0
Designated as Hedging Instrument [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		8	3
Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(15)	(36)
Designated as Hedging Instrument [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(5)	(16)
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	[1]	135	106
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(206)	(292)
Derivative, Fair Value, Net		(71)	(186)
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		148	250	$ 223	$ 182
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	[1]	42	25
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(10)	(4)
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	[1]	86	72
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	0	0
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	[1]	5	7
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(46)	(113)
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	[1]	2	2
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(150)	(175)
Commodity Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		6	3
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(22)	(50)
Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		1	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0	0
Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0	0
Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		2	1
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(14)	(33)
Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		3	2
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(8)	(17)
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		15	7
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(10)	(9)
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		15	7
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(4)	(3)
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(6)	(6)
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		8	3
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(3)	(5)
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0	0
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		8	3
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0	0
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(3)	(4)
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		$ 0	$ (1)
[1]	The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31, 2016 and 2015, a net regulatory asset of $148 million and $250 million, respectively, was recorded related to the net derivative liability of $71 million and $186 million, respectively. The difference between the net regulatory asset and the net derivative liability relates primarily to a power purchase agreement derivative at BHE Renewables.

Risk Management and Hedging 145

Risk Management and Hedging Activities - Not Designated as Hedging Contracts (Details) - Commodity Contract [Member] - Not Designated as Hedging Instrument [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Beginning balance	$ 250	$ 223	$ 182
Changes In Fair Value Derivatives Recognized In Regulatory Assets Or Liabilities, Net	(30)	128	96
Net Gains (Losses) Reclassified To Operating Revenue	(5)	1	(32)
Net losses reclassified to cost of sales	(67)	(102)	(23)
Ending balance	$ 148	$ 250	$ 223

Risk Management and Hedging 146

Risk Management and Hedging Activities - Designated as Hedging Contracts (Details) - Designated as Hedging Instrument [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accumulated Other Comprehensive (Income) Loss, Net, Derivatives [Roll Forward]
Cash flow hedge ineffectiveness	insignificant	Insignificant	Insignificant
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ (14)
Commodity Contract [Member]
Accumulated Other Comprehensive (Income) Loss, Net, Derivatives [Roll Forward]
Beginning balance	46	$ 32	$ 12
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	26	52	(6)
Net gains reclassified to operating revenue	1	9	0
Net (losses) gains reclassified to cost of sales	(57)	(47)	26
Ending balance	$ 16	$ 46	$ 32

Risk Management and Hedging 147

Risk Management and Hedging Activities - Derivative Contract Volumes (Details) gal in Millions, MWh in Millions, Dth in Millions, $ in Millions	Dec. 31, 2016USD ($)galDthMWh	Dec. 31, 2015USD ($)galDthMWh
Commodity Contract [Member] | Electricity purchases (sales), net, in megawatt hours [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	5	10
Commodity Contract [Member] | Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	271	317
Commodity Contract [Member] | Fuel purchases (in gallons) [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | gal	11	11
Interest Rate Contract [Member] | Interest Rate Swap [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Notional Amount	$ (714)	$ (653)
Interest Rate Contract [Member] | Mortgage Sale Commitments, Net [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Notional Amount	$ (309)	$ (312)

Risk Management and Hedging 148

Risk Management and Hedging Activities - Collateral and Contingent Features (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 190	$ 288
Collateral Already Posted, Aggregate Fair Value	69	75
Additional Collateral, Aggregate Fair Value	$ 110	$ 198

Risk Management and Hedging 149

Risk Management and Hedging Activities - PacifiCorp - Balance Sheet Location (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		$ (77)	$ (237)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		74	103
Derivative Assets (Liabilities), at Fair Value, Net		(3)	(134)
Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		48	28
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		48	28
Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(60)	(145)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		13	40
Derivative Assets (Liabilities), at Fair Value, Net		(47)	(105)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(66)	(188)
Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		47	28
Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(45)	(109)
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	[1]	135	106
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(206)	(292)
Derivative, Fair Value, Net		(71)	(186)
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		148	250	$ 223	$ 182
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	[1]	42	25
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(10)	(4)
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	[1]	5	7
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(46)	(113)
PacifiCorp [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(77)	(136)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		69	75
Derivative Assets (Liabilities), at Fair Value, Net		(8)	(61)
PacifiCorp [Member] | Commodity Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		18	9
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		18	9
PacifiCorp [Member] | Commodity Contract [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		2	0
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		2	0
PacifiCorp [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(13)	(56)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		10	18
Derivative Assets (Liabilities), at Fair Value, Net		(3)	(38)
PacifiCorp [Member] | Commodity Contract [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(84)	(89)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		59	57
Derivative Assets (Liabilities), at Fair Value, Net		(25)	(32)
PacifiCorp [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		27	12
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(104)	(148)
Derivative, Fair Value, Net		(77)	(136)
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		73	133	$ 85	$ 55
PacifiCorp [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		24	10
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(6)	(1)
Derivative, Fair Value, Net		18	9
PacifiCorp [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		2	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0	0
Derivative, Fair Value, Net		2	0
PacifiCorp [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		1	2
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(14)	(58)
Derivative, Fair Value, Net		(13)	(56)
PacifiCorp [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(84)	(89)
Derivative, Fair Value, Net		$ (84)	$ (89)
[1]	The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31, 2016 and 2015, a net regulatory asset of $148 million and $250 million, respectively, was recorded related to the net derivative liability of $71 million and $186 million, respectively. The difference between the net regulatory asset and the net derivative liability relates primarily to a power purchase agreement derivative at BHE Renewables.

Risk Management and Hedging 150

Risk Management and Hedging Activities - PacifiCorp - Not Designated as Hedging Contracts (Details) - Not Designated as Hedging Instrument [Member] - Commodity Contract [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Beginning balance	$ 250	$ 223	$ 182
Changes In Fair Value Derivatives Recognized In Regulatory Assets Or Liabilities, Net	(30)	128	96
Net Gains (Losses) Reclassified To Operating Revenue	(5)	1	(32)
Ending balance	148	250	223
PacifiCorp [Member]
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Beginning balance	133	85	55
Changes In Fair Value Derivatives Recognized In Regulatory Assets Or Liabilities, Net	(27)	82	45
Net Gains (Losses) Reclassified To Operating Revenue	10	40	(4)
Net Gains (Losses) Reclassified To Cost Of Domestic Regulated Electric	(43)	(74)	(11)
Ending balance	$ 73	$ 133	$ 85

Risk Management and Hedging 151

Risk Management and Hedging Activities - PacifiCorp - Derivative Contract Volumes (Details) - Commodity Contract [Member] gal in Millions, MWh in Millions, Dth in Millions	Dec. 31, 2016galDthMWh	Dec. 31, 2015galDthMWh
Electricity purchases (sales), net, in megawatt hours [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	5	10
Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	271	317
Fuel purchases (in gallons) [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | gal	11	11
PacifiCorp [Member] | Electricity purchases (sales), net, in megawatt hours [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	(3)	1
PacifiCorp [Member] | Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	84	111
PacifiCorp [Member] | Fuel purchases (in gallons) [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | gal	11	11

Risk Management and Hedging 152

Risk Management and Hedging Activities - PacifiCorp - Collateral and Contingent Features (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 190	$ 288
Collateral Already Posted, Aggregate Fair Value	69	75
Additional Collateral, Aggregate Fair Value	110	198
PacifiCorp [Member]
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	97	142
Collateral Already Posted, Aggregate Fair Value	69	75
Additional Collateral, Aggregate Fair Value	$ 22	$ 64

Risk Management and Hedging 153

Risk Management and Hedging Activities - MEC - Balance Sheet Location (Details) - USD ($) $ in Millions		Dec. 31, 2016		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		$ (77)		$ (237)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		74		103
Derivative Assets (Liabilities), at Fair Value, Net		(3)		(134)
Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		48		28
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0		0
Derivative Assets (Liabilities), at Fair Value, Net		48		28
Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(60)		(145)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		13		40
Derivative Assets (Liabilities), at Fair Value, Net		(47)		(105)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(66)		(188)
Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		47		28
Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(45)		(109)
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(11)		(49)
Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		1		0
Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(15)		(36)
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(71)		(186)
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		148		250	$ 223	$ 182
MidAmerican Energy Company [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		4		(72)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		1		28
Derivative Assets (Liabilities), at Fair Value, Net		5		(44)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		6		9
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0		0
Derivative Assets (Liabilities), at Fair Value, Net		6		9
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		2		4
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0		0
Derivative Assets (Liabilities), at Fair Value, Net		2		4
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(3)		(62)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		1		22
Derivative Assets (Liabilities), at Fair Value, Net		(2)		(40)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(1)		(23)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0		6
Derivative Assets (Liabilities), at Fair Value, Net		(1)		(17)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	[1]	10		23
Derivative Liability, Fair Value, Gross Liability	[1]	(6)		(49)
Derivative, Fair Value, Net	[1]	4		(26)
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		(4)		20	$ 38	$ 10
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	[1]	8		12
Derivative Liability, Fair Value, Gross Liability	[1]	(2)		(3)
Derivative, Fair Value, Net	[1]	6		9
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	[1]	2		4
Derivative Liability, Fair Value, Gross Liability	[1]	0		0
Derivative, Fair Value, Net	[1]	2		4
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	[1]	0		5
Derivative Liability, Fair Value, Gross Liability	[1]	(3)		(36)
Derivative, Fair Value, Net	[1]	(3)		(31)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	[1]	0		2
Derivative Liability, Fair Value, Gross Liability	[1]	(1)		(10)
Derivative, Fair Value, Net	[1]	(1)		(8)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		0		3
Derivative Liability, Fair Value, Gross Liability		0		(49)
Derivative, Fair Value, Net		0	[2]	(46)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		0		0
Derivative Liability, Fair Value, Gross Liability		0		0
Derivative, Fair Value, Net		0	[2]	0
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		0		0
Derivative Liability, Fair Value, Gross Liability		0		0
Derivative, Fair Value, Net		0	[2]	0
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		0		1
Derivative Liability, Fair Value, Gross Liability		0		(32)
Derivative, Fair Value, Net		0	[2]	(31)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		0		2
Derivative Liability, Fair Value, Gross Liability		0		(17)
Derivative, Fair Value, Net		$ 0	[2]	$ (15)
[1]	(1)MidAmerican Energy's commodity derivatives not designated as hedging contracts are generally included in regulated rates. Accordingly, as of December 31, 2016, a net regulatory liability of $4 million was recorded related to the net derivative asset of $4 million, and as of December 31, 2015, a net regulatory asset of $20 million was recorded related to the net derivative liability of $26 million
[2]	(2)The changes in derivative values from December 31, 2015, are substantially due to the transfer of MidAmerican Energy's unregulated retail services business to a subsidiary of BHE.

Risk Management and Hedging 154

Risk Management and Hedging Activities Risk Management and Hedging Activities - MEC - Not Designated as Hedging Contracts (Details) - Commodity Contract [Member] - Not Designated as Hedging Instrument [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Beginning balance	$ 250	$ 223	$ 182
Changes In Fair Value Derivatives Recognized In Regulatory Assets Or Liabilities, Net	(30)	128	96
Net Gains (Losses) Reclassified To Operating Revenue	(5)	1	(32)
Ending balance	148	250	223
MidAmerican Energy Company [Member]
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Beginning balance	20	38	10
Changes In Fair Value Derivatives Recognized In Regulatory Assets Or Liabilities, Net	3	40	61
Net Gains (Losses) Reclassified To Operating Revenue	(15)	(42)	(28)
Net Gains (Losses) Reclassified To Cost Of Domestic Regulated Electric	0	(1)	(1)
Net Gains (Losses) Reclassified To Cost Of Natural Gas Purchases	(12)	(15)	(4)
Ending balance	(4)	20	38
Derivative, Gain (Loss) on Derivative, Net	0	(4)	15
Other Revenue Net [Member] | MidAmerican Energy Company [Member]
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Derivative, Gain (Loss) on Derivative, Net	0	15	6
Cost Of Natural Gas [Member] | MidAmerican Energy Company [Member]
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Derivative, Gain (Loss) on Derivative, Net	0	2	0
Cost Of Sales Nonregulated [Member] | MidAmerican Energy Company [Member]
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Derivative, Gain (Loss) on Derivative, Net	$ 0	$ (21)	$ 9

Risk Management and Hedging 155

Risk Management and Hedging Activities - MEC - Designated as Hedging Activities (Details) - Designated as Hedging Instrument [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accumulated Other Comprehensive (Income) Loss, Net, Derivatives [Roll Forward]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ (14)
Commodity Contract [Member]
Accumulated Other Comprehensive (Income) Loss, Net, Derivatives [Roll Forward]
Beginning balance	46	$ 32	$ 12
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	(26)	(52)	6
Ending balance	16	46	32
Commodity Contract [Member] | MidAmerican Energy Company [Member]
Accumulated Other Comprehensive (Income) Loss, Net, Derivatives [Roll Forward]
Beginning balance	45	34	11
Cumulative Net Gain (Loss) From Cash Flow Hedges, Before Taxes Transferred to Affiliate	(45)	0	0
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	0	58	(3)
Cash Flow Hedge Gain (Loss) Reclassified To Cost Of Sales Nonregulated	0	(47)	26
Ending balance	$ 0	$ 45	$ 34

Risk Management and Hedging 156

Risk Management and Hedging Activities - MEC - Derivative Contract Volumes (Details) - Commodity Contract [Member] MWh in Millions, Dth in Millions	Dec. 31, 2016DthMWh	Dec. 31, 2015DthMWh
Electricity purchases (sales), net, in megawatt hours [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	5	10
Electricity purchases (sales), net, in megawatt hours [Member] | MidAmerican Energy Company [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	0	15
Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	271	317
Natural gas purchases, in decatherms [Member] | MidAmerican Energy Company [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	18	17

Risk Management and Hedging 157

Risk Management and Hedging Activities - MEC - Collateral and Contingent Features (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 190	$ 288
Additional Collateral, Aggregate Fair Value	110	198
Collateral Already Posted, Aggregate Fair Value	69	75
MidAmerican Energy Company [Member]
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	3	66
Additional Collateral, Aggregate Fair Value	2	55
Collateral Already Posted, Aggregate Fair Value	$ 0	$ 0

Risk Management and Hedging 158

Risk Management and Hedging Activities Risk Management and Hedging Activities - NPC - Balance Sheet Location (Details) - Commodity Contract [Member] - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	$ 206	$ 292
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		148	250	$ 223	$ 182
Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	46	113
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		27	46
Nevada Power Company [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[2]	7	8
Nevada Power Company [Member] | Not Designated as Hedging Instrument [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[2]	7	14
Nevada Power Company [Member] | Fair Value, Measurements, Recurring [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		14	22
Nevada Power Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		14	22
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		$ (14)	$ (22)
[1]	The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31, 2016 and 2015, a net regulatory asset of $148 million and $250 million, respectively, was recorded related to the net derivative liability of $71 million and $186 million, respectively. The difference between the net regulatory asset and the net derivative liability relates primarily to a power purchase agreement derivative at BHE Renewables.
[2]	Nevada Power's commodity derivatives not designated as hedging contracts are included in regulated rates and as of December 31, 2016 and 2015, a regulatory asset of $14 million and $22 million, respectively, was recorded related to the derivative liability of $14 million and $22 million, respectively.

Risk Management and Hedging 159

Risk Management and Hedging Activities Risk Management and Hedging Activities - NPC - Derivative Contract Volumes (Details) - Commodity Contract [Member] MWh in Millions, Dth in Millions	Dec. 31, 2016DthMWh	Dec. 31, 2015DthMWh
Electricity purchases (sales), net, in megawatt hours [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	(5)	(10)
Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	(271)	(317)
Nevada Power Company [Member] | Electricity purchases (sales), net, in megawatt hours [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	(2)	(2)
Nevada Power Company [Member] | Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	(114)	(126)

Risk Management and Hedging 160

Risk Management and Hedging Activities Risk Management and Hedging Activities - NPC - Collateral and Contingent Features (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 190	$ 288
Nevada Power Company [Member]
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 2	$ 3

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Millions		Dec. 31, 2016		Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral receivable (payable), offset against derivative positions		$ 74		$ 103
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[1]	(22)		(16)
Assets, Fair Value Disclosure		2,878		2,692
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	96		119
Derivative Liability		(145)		(237)
Cash collateral receivable (payable), offset against derivative positions		74	[1]	103
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		2,339		2,173
Derivative Liability		(3)		(13)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		467		393
Derivative Liability		(210)		(296)
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		94		142
Derivative Liability		(28)		(47)
Mortgage loans held for sale [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		359		327
Mortgage loans held for sale [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Mortgage loans held for sale [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		359		327
Mortgage loans held for sale [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	586		421
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	586		421
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	0		0
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	0		0
United States government obligations [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		161		133
United States government obligations [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		161		133
United States government obligations [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
United States government obligations [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
International governement obligations [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		3		2
International governement obligations [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
International governement obligations [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		3		2
International governement obligations [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Corporate obligations [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		36		39
Corporate obligations [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Corporate obligations [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		36		39
Corporate obligations [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Municipal Bonds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		1
Municipal Bonds [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Municipal Bonds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		1
Municipal Bonds [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Agency, asset and mortgage-backed obligations [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		3
Agency, asset and mortgage-backed obligations [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Agency, asset and mortgage-backed obligations [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		3
Agency, asset and mortgage-backed obligations [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Auction Rate Securities [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				44
Auction Rate Securities [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				0
Auction Rate Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				0
Auction Rate Securities [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				44
United States companies [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		250		239
United States companies [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		250		239
United States companies [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
United States companies [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
International companies [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		1,190		1,244
International companies [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		1,190		1,244
International companies [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
International companies [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Investment funds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		147		136
Investment funds [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		147		136
Investment funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Investment funds [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[1]	(22)		(16)
Derivative assets		119		93
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	96		119
Derivative Liability		(132)		(223)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		5		0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		2		13
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		49		16
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		199		283
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		87		93
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		27		46
Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		23		10
Derivative Liability		(13)		(14)
Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0		0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		1		0
Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		16		5
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		11		13
Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		7		5
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		$ 1		$ 1
[1]	Represents netting under master netting arrangements and a net cash collateral receivable of $74 million and $103 million as of December 31, 2016 and 2015, respectively.
[2]	Amounts are included in cash and cash equivalents; other current assets; and noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.

Fair Value Measurements - Level

Fair Value Measurements - Level 3 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Commodity [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 47	$ 51	$ 60
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	8	19	19
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)	(2)	(7)	0
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net	(11)	(19)	5
Purchases	1	1	1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	0	0	0
Settlements	17	2	1
Transfers from level 2	0	0	(35)
Ending balance	60	47	51
Interest Rate Lock Commitments [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	4	0	0
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	121	87	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)	0	0	0
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net	0	0	0
Purchases	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	0	0	0
Settlements	(119)	(86)	0
Transfers from level 2	0	3	0
Ending balance	6	4	0
Auction Rate Securities [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	44	45	44
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	5	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)	8	(1)	1
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net	0	0	0
Purchases	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	57	0	0
Settlements	0	0	0
Transfers from level 2	0	0	0
Ending balance	$ 0	$ 44	$ 45

Fair Value Measurements - Debt

Fair Value Measurements - Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 36,116	$ 37,972
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 40,718	$ 41,785

Fair Value Measurements - Pacif

Fair Value Measurements - PacifiCorp (Details) - USD ($) $ in Millions		Dec. 31, 2016		Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		$ 74		$ 103
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[1]	(22)		(16)
Assets, Fair Value Disclosure		2,878		2,692
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	96		119
Derivative Liability		(145)		(237)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		74	[1]	103
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		2,339		2,173
Derivative Liability		(3)		(13)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		467		393
Derivative Liability		(210)		(296)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		94		142
Derivative Liability		(28)		(47)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[1]	(22)		(16)
Derivative assets		119		93
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	96		119
Derivative Liability		(132)		(223)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		5		0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(2)		(13)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		49		16
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(199)		(283)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		87		93
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(27)		(46)
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	586		421
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	586		421
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	0		0
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	0		0
Investment funds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		147		136
Investment funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		147		136
Investment funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Investment funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
PacifiCorp [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		50		37
PacifiCorp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		30		28
PacifiCorp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		27		9
PacifiCorp [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		0		3
PacifiCorp [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		69		75
PacifiCorp [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[3]	(7)		(3)
Derivative assets		20		9
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[3]	76		78
Derivative Liability		(28)		(70)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		69		75
PacifiCorp [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0		0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0		0
PacifiCorp [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		27		9
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(104)		(148)
PacifiCorp [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0		3
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0		0
PacifiCorp [Member] | Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[4]	13		13
Investment funds	[4]			15
PacifiCorp [Member] | Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[4]	13		13
Investment funds	[4]			15
PacifiCorp [Member] | Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[4]	0		0
Investment funds	[4]			0
PacifiCorp [Member] | Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[4]	0		0
Investment funds	[4]			$ 0
PacifiCorp [Member] | Investment funds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment funds		17
PacifiCorp [Member] | Investment funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment funds		17
PacifiCorp [Member] | Investment funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment funds		0
PacifiCorp [Member] | Investment funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment funds		$ 0
[1]	Represents netting under master netting arrangements and a net cash collateral receivable of $74 million and $103 million as of December 31, 2016 and 2015, respectively.
[2]	Amounts are included in cash and cash equivalents; other current assets; and noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
[3]	(1)Represents netting under master netting arrangements and a net cash collateral receivable of $69 million and $75 million as of December 31, 2016 and 2015, respectively.
[4]	(2)Amounts are included in cash and cash equivalents, other current assets and other assets on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.

Fair Value Measurements - Pa165

Fair Value Measurements - PacifiCorp - Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 36,116	$ 37,972
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	40,718	41,785
PacifiCorp [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	7,052	7,114
PacifiCorp [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 8,204	$ 8,210

Fair Value Measurements - MEC (

Fair Value Measurements - MEC (Details) - USD ($) $ in Millions		Dec. 31, 2016		Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		$ 74		$ 103
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		2,878		2,692
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[1]	(22)		(16)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	96		119
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		74	[1]	103
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		2,339		2,173
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		467		393
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		94		142
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[1]	(22)		(16)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	96		119
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		5		0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(2)		(13)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		49		16
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(199)		(283)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		87		93
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(27)		(46)
MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		477		522
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[2]	(2)		(13)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		1		28
MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		426		438
MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		52		53
MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		1		44
MidAmerican Energy Company [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		1		28
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		8		13
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[2]	(2)		(13)
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(3)		(57)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[2]	3		41
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		0		0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0		(13)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		9		8
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(3)		(61)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement		1		18
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(3)		(24)
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[3]	586		421
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[3]	586		421
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[3]	0		0
Money market mutual funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[3]	0		0
Money market mutual funds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[4]	1		56
Money market mutual funds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[4]	1		56
Money market mutual funds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[4]	0		0
Money market mutual funds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[4]	0		0
US Treasury Securities [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		161		133
US Treasury Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		161		133
US Treasury Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
US Treasury Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
US Treasury Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		161		133
US Treasury Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		161		133
US Treasury Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
US Treasury Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Foreign Government Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		3		2
Foreign Government Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Foreign Government Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		3		2
Foreign Government Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Foreign Government Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		3		2
Foreign Government Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Foreign Government Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		3		2
Foreign Government Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Domestic Corporate Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		36		39
Domestic Corporate Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Domestic Corporate Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		36		39
Domestic Corporate Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Domestic Corporate Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		36		39
Domestic Corporate Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Domestic Corporate Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		36		39
Domestic Corporate Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Municipal Bonds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		1
Municipal Bonds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Municipal Bonds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		1
Municipal Bonds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Municipal Bonds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		1
Municipal Bonds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Municipal Bonds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		1
Municipal Bonds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		3
US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		3
US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
US Government-sponsored Enterprises Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		3
US Government-sponsored Enterprises Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
US Government-sponsored Enterprises Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		2		3
US Government-sponsored Enterprises Debt Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Auction Rate Securities [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				44
Auction Rate Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				0
Auction Rate Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				0
Auction Rate Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				44
Auction Rate Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				26
Auction Rate Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				0
Auction Rate Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				0
Auction Rate Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities				26
Domestic Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		250		239
Domestic Equity Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		250		239
Domestic Equity Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Domestic Equity Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Domestic Equity Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		250		239
Domestic Equity Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		250		239
Domestic Equity Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Domestic Equity Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Foreign Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		1,190		1,244
Foreign Equity Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		1,190		1,244
Foreign Equity Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Foreign Equity Securities [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Foreign Equity Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		5		6
Foreign Equity Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		5		6
Foreign Equity Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Foreign Equity Securities [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Equity Funds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		147		136
Equity Funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		147		136
Equity Funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Equity Funds [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Equity Funds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		9		4
Equity Funds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		9		4
Equity Funds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0		0
Equity Funds [Member] | MidAmerican Energy Company [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		$ 0		$ 0
[1]	Represents netting under master netting arrangements and a net cash collateral receivable of $74 million and $103 million as of December 31, 2016 and 2015, respectively.
[2]	(1)Represents netting under master netting arrangements and a net cash collateral receivable of $1 million and $28 million as of December 31, 2016 and 2015, respectively.
[3]	Amounts are included in cash and cash equivalents; other current assets; and noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
[4]	(2)Amounts are included in cash and cash equivalents and investments and restricted cash and investments on the Balance Sheets. The fair value of these money market mutual funds approximates cost.

Fair Value Measurements - MEC -

Fair Value Measurements - MEC - Level 3 (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Auction Rate Securities [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance		$ 44	$ 45	$ 44
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings		5	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)		8	(1)	1
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net		0	0	0
Purchases		0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales		57	0	0
Settlements		0	0	0
Ending balance		0	44	45
MidAmerican Energy Company [Member] | Derivative [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance		(6)	12	(3)
Fair Value, Measurements With Unobservable Inputs Reconciliation, Recurring Basis, Transferred To Affiliate		(4)	0	0
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	[1]	0	11	12
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)		0	(7)	0
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net		(6)	(25)	6
Purchases		0	1	1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales		0	0	0
Settlements		14	2	(4)
Ending balance		(2)	(6)	12
Unrealized Gain (Loss) on Derivatives and Commodity Contracts			8	16
MidAmerican Energy Company [Member] | Auction Rate Securities [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance		26	26	23
Fair Value, Measurements With Unobservable Inputs Reconciliation, Recurring Basis, Transferred To Affiliate		0	0	0
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings		5	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)		4	0	3
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net		0	0	0
Purchases		0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales		35	0	0
Settlements		0	0	0
Ending balance		$ 0	$ 26	$ 26
[1]	(1)Changes included in earnings related to MidAmerican Energy's unregulated retail services business that was transferred to an affiliate of BHE. Refer to Note 3 for a discussion of discontinued operations. Net unrealized (losses) gains included in earnings for the years ended December 31, 2015 and 2014, related to commodity derivatives held at December 31, 2015 and 2014, totaled $8 million and $16 million, respectively.

Fair Value Measurements - ME168

Fair Value Measurements - MEC - Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 36,116	$ 37,972
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	40,718	41,785
MidAmerican Energy Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	4,301	4,271
Long-term Debt, Fair Value		$ 4,636
MidAmerican Energy Company [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 4,735

Fair Value Measurements - MidAm

Fair Value Measurements - MidAmerican Funding - Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 36,116	$ 37,972
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	40,718	41,785
MidAmerican Funding, LLC and Subsidiaries [Domain]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	4,627	4,597
Long-term Debt, Fair Value		$ 5,051
MidAmerican Funding, LLC and Subsidiaries [Domain] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 5,164

Fair Value Measurements - NPC (

Fair Value Measurements - NPC (Details) - Fair Value, Measurements, Recurring [Member] - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		$ 2,878	$ 2,692
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		2,339	2,173
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		467	393
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		94	142
Money Market Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	586	421
Money Market Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	586	421
Money Market Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	0	0
Money Market Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	0	0
Equity Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		147	136
Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		147	136
Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0	0
Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0	0
Commodity Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(2)	(13)
Commodity Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(199)	(283)
Commodity Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(27)	(46)
Nevada Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		226
Nevada Power Company [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		226
Nevada Power Company [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		0
Nevada Power Company [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		0
Nevada Power Company [Member] | Money Market Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	220
Nevada Power Company [Member] | Money Market Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	220
Nevada Power Company [Member] | Money Market Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	0
Nevada Power Company [Member] | Money Market Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	0
Nevada Power Company [Member] | Equity Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		6	5
Nevada Power Company [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		6	5
Nevada Power Company [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0	0
Nevada Power Company [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0	0
Nevada Power Company [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(14)	(22)
Nevada Power Company [Member] | Commodity Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0	0
Nevada Power Company [Member] | Commodity Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0	0
Nevada Power Company [Member] | Commodity Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		$ (14)	$ (22)
[1]	Amounts are included in cash and cash equivalents; other current assets; and noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.

Fair Value Measurements - NPC -

Fair Value Measurements - NPC - Level 3 (Details) - Commodity [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset (Liability), Net, Value	$ 60	$ 47	$ 51	$ 60
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net	(11)	(19)	5
Purchases	1	1	1
Settlements	17	2	1
Ending balance	60	47	51
Nevada Power Company [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset (Liability), Net, Value	(14)	(22)	(30)	$ (47)
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net	(4)	0	9
Settlements	12	8	8
Ending balance	$ (14)	$ (22)	$ (30)

Fair Value Measurements - NP172

Fair Value Measurements - NPC - Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 36,116	$ 37,972
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	40,718	41,785
Nevada Power Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	2,581	2,788
Nevada Power Company [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 3,040	$ 3,240

Fair Value Measurements - SPPC

Fair Value Measurements - SPPC (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt		$ 36,116	$ 37,972
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt, Fair Value		40,718	41,785
Sierra Pacific Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt		1,119	1,165
Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt, Fair Value		1,191	1,248
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		2,878	2,692
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		2,339	2,173
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		467	393
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		94	142
Fair Value, Measurements, Recurring [Member] | Sierra Pacific Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		36
Fair Value, Measurements, Recurring [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		36
Fair Value, Measurements, Recurring [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		0
Fair Value, Measurements, Recurring [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		0
Fair Value, Measurements, Recurring [Member] | Equity Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		147	136
Fair Value, Measurements, Recurring [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		147	136
Fair Value, Measurements, Recurring [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0	0
Fair Value, Measurements, Recurring [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0	0
Fair Value, Measurements, Recurring [Member] | Equity Funds [Member] | Sierra Pacific Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		1	1
Fair Value, Measurements, Recurring [Member] | Equity Funds [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		1	1
Fair Value, Measurements, Recurring [Member] | Equity Funds [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0	0
Fair Value, Measurements, Recurring [Member] | Equity Funds [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities		0	0
Fair Value, Measurements, Recurring [Member] | Money Market Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	586	421
Fair Value, Measurements, Recurring [Member] | Money Market Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	586	421
Fair Value, Measurements, Recurring [Member] | Money Market Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	0	0
Fair Value, Measurements, Recurring [Member] | Money Market Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[1]	0	0
Fair Value, Measurements, Recurring [Member] | Money Market Funds [Member] | Sierra Pacific Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	35
Fair Value, Measurements, Recurring [Member] | Money Market Funds [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	35
Fair Value, Measurements, Recurring [Member] | Money Market Funds [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	0
Fair Value, Measurements, Recurring [Member] | Money Market Funds [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities	[2]	0
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(2)	(13)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(199)	(283)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		$ (27)	(46)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Sierra Pacific Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement			(1)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement			0
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement			0
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Sierra Pacific Power Company [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement			$ (1)
[1]	Amounts are included in cash and cash equivalents; other current assets; and noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
[2]	Amounts are included in cash and cash equivalents on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.

Other, Net - MEC (Details)

Other, Net - MEC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	$ 36	$ 39	$ 42
MidAmerican Energy Company [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	14	5	10
MidAmerican Energy Company [Member] | Corporate Owned Life Insurance Income (Loss) [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	8	4	8
MidAmerican Energy Company [Member] | Available-For-Sale Securities, Gross Gain (Loss) [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	5	0	0
MidAmerican Energy Company [Member] | Other Income (Expense) [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	$ 1	$ 1	$ 2

Other, Net - MidAmerican Fundin

Other, Net - MidAmerican Funding (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	$ 36	$ 39	$ 42
MidAmerican Funding, LLC and Subsidiaries [Domain]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	19	19	18
MidAmerican Funding, LLC and Subsidiaries [Domain] | Corporate Owned Life Insurance Income (Loss) [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	8	4	8
MidAmerican Funding, LLC and Subsidiaries [Domain] | Available-For-Sale Securities, Gross Gain (Loss) [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	5	0	0
MidAmerican Funding, LLC and Subsidiaries [Domain] | Gains (Losses) on Disposition of Assets [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	3	13	0
MidAmerican Funding, LLC and Subsidiaries [Domain] | Assets Leased to Others [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	0	1	5
MidAmerican Funding, LLC and Subsidiaries [Domain] | Other Income (Expense) [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	$ 3	$ 1	$ 5

Income Taxes - Components of In

Income Taxes - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Current Federal Tax Expense (Benefit)	$ (743)	$ (929)	$ (1,872)
Current State and Local Tax Expense (Benefit)	1	29	(3)
Current foreign	55	84	129
Current Income Tax Expense (Benefit)	(687)	(816)	(1,746)
Deferred Federal Income Tax Expense (Benefit)	1,164	1,310	2,296
Deferred State and Local Income Tax Expense (Benefit)	(59)	(53)	37
Deferred foreign	(7)	17	11
Deferred Income Tax Expense (Benefit)	1,098	1,274	2,344
Other Tax Expense (Benefit)	(8)	(8)	(9)
Total income tax expense (benefit)	$ 403	$ 450	$ 589

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Effective Income Tax Rate (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	12 Months Ended
	Nov. 30, 2015	Sep. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Abstract]
Federal statutory income tax rate			35.00%	35.00%	35.00%
Income tax credits			(14.00%)	(11.00%)	(10.00%)
State income tax, net of federal income tax benefit			(1.00%)	(1.00%)	1.00%
Income tax effect of foreign income			(6.00%)	(7.00%)	(3.00%)
Equity income			(2.00%)	(2.00%)	(2.00%)
Other, net			(2.00%)	(2.00%)	(2.00%)
Effective income tax rate			14.00%	16.00%	23.00%
Production Tax Credit Carryforwards [Abstract]
Years Eligible For Renewable Energy Production Tax Credit			10 years
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
Deferred state			$ 59	$ 53	$ (37)
Related Party Tax Expense [Abstract]
Income Taxes Receivable From (Payable To) Related Parties Current			27	286
United Kingdom
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount			$ 16	$ 39
Corporate Income Tax Rate, Effective April 1, 2020 [Member] | United Kingdom
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Percent	18.00%	0.00%
Corporate Income Tax Rate, Effective April 1, 2020 further reduction [Member] | United Kingdom
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Percent		17.00%
Corporate Income Tax Rate Enacted November 2015, Effective April 1, 2017 [Member] | United Kingdom
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Percent	20.00%
Corporate Income Tax Rate Enacted November 2015, Effective April 1, 2017 19% [Member] | United Kingdom
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Percent	19.00%

Income Taxes - Components of Ne

Income Taxes - Components of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred income tax assets: [Abstract]
Federal, state and foreign carryforwards	$ 987	$ 865
Regulatory liabilities	909	834
AROs	326	317
Employee benefits	209	190
Derivative contracts	29	83
Other	707	815
Total deferred income tax assets	3,167	3,104
Valuation allowances	(64)	(35)
Total deferred income tax assets, net	3,103	3,069
Deferred income tax liabilities: [ Abstract]
Property-related items	(14,237)	(13,157)
Regulatory assets	(1,449)	(1,446)
Investments	(962)	(852)
Other	(334)	(299)
Total deferred income tax liabilities	(16,982)	(15,754)
Net deferred income tax liability	$ (13,879)	$ (12,685)

Income Taxes - Summary of Opera

Income Taxes - Summary of Operating Loss Carryforwards (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Operating Loss Carryforwards [Line Items]
Foreign carryforwards	$ 97
Deferred Tax Assets, Foreign Tax Credit, Years To Expiration	10 years
Federal [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 179	[1]
Deferred Tax Assets, Operating Loss Carryforwards	65
Deferred Tax Assets, Tax Credit Carryforwards	128	[2]
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	11,549	[1]
Deferred Tax Assets, Operating Loss Carryforwards	674
Deferred Tax Assets, Tax Credit Carryforwards	25	[2]
Foreign Tax Authority [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	352	[1]
Deferred Tax Assets, Operating Loss Carryforwards	95
Deferred Tax Assets, Tax Credit Carryforwards	0
Income Tax Authority, Name [Domain]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	12,080	[1]
Deferred Tax Assets, Operating Loss Carryforwards	834
Deferred Tax Assets, Tax Credit Carryforwards	$ 153
Minimum [Member] | Federal [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2023
Tax Credit Carryforward, Expiration Date	Dec. 31, 2023
Minimum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2017
Tax Credit Carryforward, Expiration Date	Dec. 31, 2016
Maximum [Member] | Federal [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2025
Maximum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2036
[1]	The federal net operating loss carry forwards relate principally to net operating loss carry forwards of subsidiaries that are tax residents in both the United States and the United Kingdom. The federal net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2023.
[2]	Includes $97 million of deferred foreign tax credits associated with the federal income tax on unremitted tax earnings and profit pools that will begin to be creditable and expire 10 years after the date the foreign earnings are repatriated through actual or deemed dividends. As of December 31, 2016 the statute of limitation had not begun on the foreign tax credit carryforwards.

Income Taxes - Net Unrecognized

Income Taxes - Net Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	$ 198	$ 220
Additions based on tax positions related to the current year	7	3
Additions for tax positions of prior years	6	46
Reductions for tax positions of prior years	(11)	(58)
Statute of limitations	(1)	(6)
Settlements	(67)	(6)
Interest and penalties	(4)	(1)
Ending balance	128	198
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	104	163
Unrecognized tax benefits that would not impact the effective tax rate	$ 24	$ 35

Income Taxes - PacifiCorp - Com

Income Taxes - PacifiCorp - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Income Tax Expense (Benefit) Components [Line Items]
Current Federal Tax Expense (Benefit)	$ (743)	$ (929)	$ (1,872)
Current State and Local Tax Expense (Benefit)	1	29	(3)
Current Income Tax Expense (Benefit)	(687)	(816)	(1,746)
Deferred Federal Income Tax Expense (Benefit)	1,164	1,310	2,296
Deferred State and Local Income Tax Expense (Benefit)	(59)	(53)	37
Deferred Income Tax Expense (Benefit)	1,098	1,274	2,344
Other Tax Expense (Benefit)	(8)	(8)	(9)
Income tax expense	403	450	589
PacifiCorp [Member]
Schedule of Income Tax Expense (Benefit) Components [Line Items]
Current Federal Tax Expense (Benefit)	169	130	2
Current State and Local Tax Expense (Benefit)	32	26	10
Current Income Tax Expense (Benefit)	201	156	12
Deferred Federal Income Tax Expense (Benefit)	123	148	260
Deferred State and Local Income Tax Expense (Benefit)	21	29	43
Deferred Income Tax Expense (Benefit)	144	177	303
Other Tax Expense (Benefit)	(5)	(5)	(6)
Income tax expense	$ 340	$ 328	$ 309

Income Taxes - PacifiCorp - Rec

Income Taxes - PacifiCorp - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	1.00%	1.00%	(1.00%)
Income tax credits	(14.00%)	(11.00%)	(10.00%)
Other, net	(2.00%)	(2.00%)	(2.00%)
Effective income tax rate	14.00%	16.00%	23.00%
Deferred Tax Assets, Tax Credit Carryforwards [Abstract]
Years Eligible For Renewable Energy Production Tax Credit	10 years
PacifiCorp [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	3.00%	3.00%	3.00%
Income tax credits	(6.00%)	(6.00%)	(7.00%)
Other, net	(1.00%)	0.00%	0.00%
Effective income tax rate	31.00%	32.00%	31.00%
Deferred Tax Assets, Tax Credit Carryforwards [Abstract]
Years Eligible For Renewable Energy Production Tax Credit	10 years

Income Taxes - PacifiCorp - 183

Income Taxes - PacifiCorp - Component of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities	$ 909	$ 834
AROs	326	317
Other	707	815
Total deferred income tax assets, net	3,103	3,069
Property-related items	(14,237)	(13,157)
Regulatory assets	(1,449)	(1,446)
Other	(334)	(299)
Total deferred income tax liabilities	(16,982)	(15,754)
Net deferred income tax liability	(13,879)	(12,685)
PacifiCorp [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities	393	374
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits	202	189
Deferred Tax Assets, Derivative Instruments And Unamortized Contract Values	67	94
Deferred Tax Assets, Operating Loss and Tax Credit Carryforwards, State and Local	69	68
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Contingencies	12	67
AROs	78	81
Other	82	88
Total deferred income tax assets, net	903	961
Property-related items	(5,161)	(5,030)
Regulatory assets	(586)	(639)
Other	(36)	(42)
Total deferred income tax liabilities	(5,783)	(5,711)
Net deferred income tax liability	$ (4,880)	$ (4,750)

Income Taxes - PacifiCorp - Sum

Income Taxes - PacifiCorp - Summary of Operating Loss Carryforwards (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 11,549	[1]
Deferred Tax Assets, Operating Loss Carryforwards	674
Deferred Tax Assets, Tax Credit Carryforwards	25	[2]
PacifiCorp [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	1,415
Deferred Tax Assets, Operating Loss Carryforwards	52
Deferred Tax Assets, Tax Credit Carryforwards	$ 17
Minimum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2017
Tax Credit Carryforward, Expiration Date	Dec. 31, 2016
Minimum [Member] | PacifiCorp [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2017
Minimum [Member] | PacifiCorp [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2017
Maximum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2036
Maximum [Member] | PacifiCorp [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2032
[1]	The federal net operating loss carry forwards relate principally to net operating loss carry forwards of subsidiaries that are tax residents in both the United States and the United Kingdom. The federal net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2023.
[2]	Includes $97 million of deferred foreign tax credits associated with the federal income tax on unremitted tax earnings and profit pools that will begin to be creditable and expire 10 years after the date the foreign earnings are repatriated through actual or deemed dividends. As of December 31, 2016 the statute of limitation had not begun on the foreign tax credit carryforwards.

Income Taxes Income Taxes - Pac

Income Taxes Income Taxes - PacifiCorp - Net Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits	$ 128	$ 198	$ 220
PacifiCorp [Member]
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits	$ 12	$ 13

Income Taxes Income Taxes - MEC

Income Taxes Income Taxes - MEC - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Components of Income Tax Expense (Benefit) [Line Items]
Current Federal Tax Expense (Benefit)	$ (743)	$ (929)	$ (1,872)
Current State and Local Tax Expense (Benefit)	1	29	(3)
Current Income Tax Expense (Benefit)	(687)	(816)	(1,746)
Deferred Federal Income Tax Expense (Benefit)	1,164	1,310	2,296
Deferred State and Local Income Tax Expense (Benefit)	(59)	(53)	37
Deferred Income Tax Expense (Benefit)	1,098	1,274	2,344
Other Tax Expense (Benefit)	(8)	(8)	(9)
Income tax (benefit) expense	403	450	589
MidAmerican Energy Company [Member]
Components of Income Tax Expense (Benefit) [Line Items]
Current Federal Tax Expense (Benefit)	(479)	(415)	(411)
Current State and Local Tax Expense (Benefit)	(14)	(6)	(4)
Current Income Tax Expense (Benefit)	(493)	(421)	(415)
Deferred Federal Income Tax Expense (Benefit)	366	281	298
Deferred State and Local Income Tax Expense (Benefit)	(4)	(6)	2
Deferred Income Tax Expense (Benefit)	362	275	300
Other Tax Expense (Benefit)	(1)	(1)	(1)
Income tax (benefit) expense	$ (132)	$ (147)	$ (116)

Income Taxes Income Taxes - 187

Income Taxes Income Taxes - MEC - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, Tax Credit, Percent	(14.00%)	(11.00%)	(10.00%)
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	1.00%	1.00%	(1.00%)
Other, net	(2.00%)	(2.00%)	(2.00%)
Effective income tax rate	14.00%	16.00%	23.00%
Years Eligible For Renewable Energy Production Tax Credit	10 years
MidAmerican Energy Company [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, Tax Credit, Percent	(61.00%)	(71.00%)	(65.00%)
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	(3.00%)	(2.00%)	0.00%
Effective Income Tax Rate Reconciliation Regulatory Differences	(3.00%)	(12.00%)	(9.00%)
Other, net	0.00%	1.00%	(2.00%)
Effective income tax rate	(32.00%)	(49.00%)	(41.00%)
Years Eligible For Renewable Energy Production Tax Credit	10 years

Income Taxes - MEC - Components

Income Taxes - MEC - Components of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities	$ 909	$ 834
Derivative contracts	29	83
AROs	326	317
Other	707	815
Total deferred income tax assets, net	3,103	3,069
Property-related items	(14,237)	(13,157)
Regulatory assets	(1,449)	(1,446)
Other	(334)	(299)
Total deferred income tax liabilities	(16,982)	(15,754)
Net deferred income tax liability	(13,879)	(12,685)
MidAmerican Energy Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities	333	327
AROs	66	66
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits	230	214
Other	74	88
Total deferred income tax assets, net	703	695
Property-related items	(3,763)	(3,321)
Regulatory assets	(471)	(418)
Other	(41)	(17)
Total deferred income tax liabilities	(4,275)	(3,756)
Net deferred income tax liability	$ (3,572)	$ (3,061)

Income Taxes - MEC - Summary of

Income Taxes - MEC - Summary of Operating Loss Carryforwards (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Operating Loss Carryforwards [Line Items]
Federal, state and foreign carryforwards		$ 987	$ 865
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	[1]	11,549
MidAmerican Energy Company [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Federal, state and foreign carryforwards		25
Operating Loss Carryforwards		$ 549
MidAmerican Energy Company [Member] | Minimum [Member]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss and Tax Credit Carry Forwards, Domestic Federal and State, ExpirationDate		2,017
MidAmerican Energy Company [Member] | Maximum [Member]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss and Tax Credit Carry Forwards, Domestic Federal and State, ExpirationDate		2,035
[1]	The federal net operating loss carry forwards relate principally to net operating loss carry forwards of subsidiaries that are tax residents in both the United States and the United Kingdom. The federal net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2023.

Income Taxes - MEC - Net Unreco

Income Taxes - MEC - Net Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	$ 198	$ 220
Additions based on tax positions related to the current year	7	3
Additions for tax positions of prior years	6	46
Reductions for tax positions of prior years	(11)	(58)
Statute of limitations	(1)	(6)
Settlements	(67)	(6)
Interest and penalties	(4)	(1)
Ending balance	128	198
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	104	163
MidAmerican Energy Company [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	10	26
Additions based on tax positions related to the current year	0	3
Additions for tax positions of prior years	10	47
Unrecognized Tax Benefits, Decrease Resulting from Current Period Tax Positions	(2)	(6)
Reductions for tax positions of prior years	(8)	(46)
Statute of limitations	0	(5)
Settlements	0	(6)
Interest and penalties	0	(3)
Ending balance	10	$ 10
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	$ 29

Income Taxes - MidAmerican Fund

Income Taxes - MidAmerican Funding - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Components of Income Tax Expense (Benefit) [Line Items]
Current Federal Tax Expense (Benefit)	$ (743)	$ (929)	$ (1,872)
Current State and Local Tax Expense (Benefit)	1	29	(3)
Current Income Tax Expense (Benefit)	(687)	(816)	(1,746)
Deferred Federal Income Tax Expense (Benefit)	1,164	1,310	2,296
Deferred State and Local Income Tax Expense (Benefit)	(59)	(53)	37
Deferred Income Tax Expense (Benefit)	1,098	1,274	2,344
Other Tax Expense (Benefit)	(8)	(8)	(9)
Income tax (benefit) expense	403	450	589
MidAmerican Funding, LLC and Subsidiaries [Domain]
Components of Income Tax Expense (Benefit) [Line Items]
Current Federal Tax Expense (Benefit)	(485)	(418)	(414)
Current State and Local Tax Expense (Benefit)	(16)	(8)	(5)
Current Income Tax Expense (Benefit)	(501)	(426)	(419)
Deferred Federal Income Tax Expense (Benefit)	367	282	296
Deferred State and Local Income Tax Expense (Benefit)	(4)	(5)	2
Deferred Income Tax Expense (Benefit)	363	277	298
Other Tax Expense (Benefit)	(1)	(1)	(1)
Income tax (benefit) expense	$ (139)	$ (150)	$ (122)

Income Taxes Income Taxes - Mid

Income Taxes Income Taxes - MidAmerican Funding - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Income tax credits	(14.00%)	(11.00%)	(10.00%)
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	1.00%	1.00%	(1.00%)
Other, net	(2.00%)	(2.00%)	(2.00%)
Effective income tax rate	14.00%	16.00%	23.00%
Years Eligible For Renewable Energy Production Tax Credit	10 years
MidAmerican Funding, LLC and Subsidiaries [Domain]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Income tax credits	(64.00%)	(72.00%)	(68.00%)
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	(3.00%)	(3.00%)	(1.00%)
Effective Income Tax Rate Reconciliation Regulatory Differences	(3.00%)	(12.00%)	(10.00%)
Other, net	0.00%	1.00%	(1.00%)
Effective income tax rate	(35.00%)	(51.00%)	(45.00%)
Years Eligible For Renewable Energy Production Tax Credit	10 years

Income Taxes Income Taxes - 193

Income Taxes Income Taxes - MidAmerican Funding - Components of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities		$ 909	$ 834
Derivative contracts		29	83
AROs		326	317
Other		707	815
Total deferred income tax assets, net		3,103	3,069
Property-related items		(14,237)	(13,157)
Regulatory assets		(1,449)	(1,446)
Other		(334)	(299)
Total deferred income tax liabilities		(16,982)	(15,754)
Net deferred income tax liability		(13,879)	(12,685)
Federal, state and foreign carryforwards		987	865
MidAmerican Funding, LLC and Subsidiaries [Domain]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities		333	327
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits		66	66
AROs		230	214
Other		82	97
Total deferred income tax assets, net		711	704
Property-related items		(3,767)	(3,326)
Regulatory assets		(471)	(418)
Other		(41)	(16)
Total deferred income tax liabilities		(4,279)	(3,760)
Net deferred income tax liability		(3,568)	$ (3,056)
State and Local Jurisdiction [Member]
Deferred Tax Assets and Liabilities [Line Items]
Operating Loss Carryforwards	[1]	11,549
State and Local Jurisdiction [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain]
Deferred Tax Assets and Liabilities [Line Items]
Federal, state and foreign carryforwards		25
Operating Loss Carryforwards		$ 549
Minimum [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain]
Deferred Tax Assets and Liabilities [Line Items]
Deferred Tax Assets, Operating Loss and Tax Credit Carry Forwards, Domestic Federal and State, ExpirationDate		2,017
Maximum [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain]
Deferred Tax Assets and Liabilities [Line Items]
Deferred Tax Assets, Operating Loss and Tax Credit Carry Forwards, Domestic Federal and State, ExpirationDate		2,035
[1]	The federal net operating loss carry forwards relate principally to net operating loss carry forwards of subsidiaries that are tax residents in both the United States and the United Kingdom. The federal net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2023.

Income Taxes - MidAmerican F194

Income Taxes - MidAmerican Funding - Net Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	$ 198	$ 220
Additions based on tax positions related to the current year	7	3
Additions for tax positions of prior years	6	46
Reductions for tax positions of prior years	(11)	(58)
Statute of limitations	(1)	(6)
Settlements	(67)	(6)
Interest and penalties	(4)	(1)
Ending balance	128	198
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	104	163
MidAmerican Funding, LLC and Subsidiaries [Domain]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	10	26
Additions based on tax positions related to the current year	0	4
Additions for tax positions of prior years	10	46
Unrecognized Tax Benefits, Decrease Resulting from Current Period Tax Positions	(2)	(6)
Reductions for tax positions of prior years	(8)	(46)
Statute of limitations	0	(5)
Settlements	0	(6)
Interest and penalties	0	(3)
Ending balance	10	$ 10
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	$ 30

Income Taxes - NPC - Components

Income Taxes - NPC - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Components of Income Tax Expense (Benefit) [Line Items]
Current federal tax expense (benefit)	$ (687)	$ (816)	$ (1,746)
Deferred federal income tax expense (benefit)	1,098	1,274	2,344
Other Tax Expense (Benefit)	(8)	(8)	(9)
Income tax expense	403	450	589
Nevada Power Company [Member]
Components of Income Tax Expense (Benefit) [Line Items]
Current federal tax expense (benefit)	68	0	0
Deferred federal income tax expense (benefit)	79	163	131
Other Tax Expense (Benefit)	(1)	(1)	(1)
Income tax expense	$ 146	$ 162	$ 130

Income Taxes - NPC - Reconcilia

Income Taxes - NPC - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Contingency [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Other, net	(2.00%)	(2.00%)	(2.00%)
Effective income tax rate	14.00%	16.00%	23.00%
Nevada Power Company [Member]
Income Tax Contingency [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Merger Charges, Percent	0.00%	1.00%	1.00%
Other, net	(1.00%)	0.00%	0.00%
Effective income tax rate	34.00%	36.00%	36.00%

Income Taxes - NPC - Compone197

Income Taxes - NPC - Components of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities	$ 909	$ 834
Employee benefits	209	190
Other	707	815
Total deferred income tax assets	3,167	3,104
Valuation allowances	(64)	(35)
Total deferred income tax assets, net	3,103	3,069
Property-related items	(14,237)	(13,157)
Regulatory assets	(1,449)	(1,446)
Other	(334)	(299)
Total deferred income tax liabilities	(16,982)	(15,754)
Deferred Tax Liabilities, Net	13,879	12,685
Nevada Power Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Deferred Tax Assets, Tax Deferred Expense, Leases	170	174
Regulatory liabilities	83	47
Employee benefits	29	30
Deferred Tax Assets, Customer Advances	23	22
Deferred Tax Assets, Operating Loss and Credit Carryforwards, Federal	5	15
Other	16	17
Total deferred income tax assets	326	305
Valuation allowances	(5)	(5)
Total deferred income tax assets, net	321	300
Property-related items	(1,293)	(1,242)
Regulatory assets	(321)	(275)
Deferred Tax Liabilities, Tax Deferred Expense, Leases	(165)	(169)
Other	(16)	(19)
Total deferred income tax liabilities	(1,795)	(1,705)
Deferred Tax Liabilities, Net	$ 1,474	$ 1,405

Income Taxes - NPC - Summary of

Income Taxes - NPC - Summary of Operating Loss Carryforwards (Details) - Nevada Power Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Tax Credit Carryforwards	$ 5
Minimum [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2017
Maximum [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2028

Income Taxes - SPPC - Component

Income Taxes - SPPC - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Components of Income Tax Expense (Benefit) [Line Items]
Current federal tax expense (benefit)	$ (687)	$ (816)	$ (1,746)
Deferred Federal Income Tax Expense (Benefit)	1,164	1,310	2,296
Deferred State and Local Income Tax Expense (Benefit)	(59)	(53)	37
Deferred Income Tax Expense (Benefit)	1,098	1,274	2,344
Other Tax Expense (Benefit)	(8)	(8)	(9)
Income tax expense	403	450	589
Sierra Pacific Power Company [Member]
Components of Income Tax Expense (Benefit) [Line Items]
Deferred Federal Income Tax Expense (Benefit)	50	48	48
Other Tax Expense (Benefit)	(1)	(1)	(1)
Income tax expense	$ 49	$ 47	$ 47

Income Taxes - SPPC - Reconcili

Income Taxes - SPPC - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Other, net	(2.00%)	(2.00%)	(2.00%)
Effective income tax rate	14.00%	16.00%	23.00%
Sierra Pacific Power Company [Member]
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation Regulatory Differences	1.00%	1.00%	1.00%
Other, net	1.00%	0.00%	(1.00%)
Effective income tax rate	37.00%	36.00%	35.00%

Income Taxes - SPPC - Compon201

Income Taxes - SPPC - Components of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Assets and Liabilities [Line Items]
Employee benefits	$ 209	$ 190
Regulatory liabilities	909	834
Derivative contracts	29	83
Other	707	815
Total deferred income tax assets	3,167	3,104
Property-related items	(14,237)	(13,157)
Regulatory assets	(1,449)	(1,446)
Other	(334)	(299)
Total deferred income tax liabilities	(16,982)	(15,754)
Net deferred income tax liability	(13,879)	(12,685)
Sierra Pacific Power Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Deferred Tax Assets, Operating Loss and Credit Carryforwards, Federal	25	39
Employee benefits	22	25
Regulatory liabilities	16	19
Deferred Tax Assets, Tax Deferred Expense, Leases	12	13
Deferred Tax Assets, Customer Advances	9	8
Derivative contracts	5	5
Other	6	7
Total deferred income tax assets	95	116
Property-related items	(562)	(538)
Regulatory assets	(124)	(121)
Deferred Tax Liabilities, Tax Deferred Expense, Leases	(12)	(13)
Other	(14)	(14)
Total deferred income tax liabilities	(712)	(686)
Net deferred income tax liability	$ (617)	$ (570)

Income Taxes - SPPC - Summary o

Income Taxes - SPPC - Summary of Operating Loss Carryforwards (Details) - Sierra Pacific Power Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 55
Deferred Tax Assets, Operating Loss Carryforwards	19
Deferred Tax Assets, Tax Credit Carryforwards	$ 6
Minimum [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2031
Tax Credit Carryforward, Expiration Date	Dec. 31, 2021
Maximum [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2033
Tax Credit Carryforward, Expiration Date	Dec. 31, 2032

Supplemental Cash Flow Discl203

Supplemental Cash Flow Disclosures (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Interest paid, net of amounts capitalized		$ 1,673	$ 1,764	$ 1,585
Income Taxes Paid, Net	[1]	(1,016)	(1,666)	(635)
Related Party Transaction, Cash Received for Income Taxes, Net		1,100	1,800	764
Capital Expenditures Incurred but Not yet Paid		$ 547	$ 718	$ 1,143
[1]	Includes $1.1 billion, $1.8 billion and $764 million of income taxes received from Berkshire Hathaway in 2016, 2015 and 2014, respectively.

Supplemental Cash Flow Discl204

Supplemental Cash Flow Disclosures - PacifiCorp (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		$ 1,673	$ 1,764	$ 1,585
Income Taxes Paid, Net	[1]	(1,016)	(1,666)	(635)
Accruals related to property, plant and equipment additions		547	718	1,143
PacifiCorp [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		350	342	340
Income Taxes Paid, Net		201	40	161
Accruals related to property, plant and equipment additions		101	147	140
Accounts receivable related to property, plant and equipment sales		$ 0	$ 40	$ 0
[1]	Includes $1.1 billion, $1.8 billion and $764 million of income taxes received from Berkshire Hathaway in 2016, 2015 and 2014, respectively.

Supplemental Cash Flow Discl205

Supplemental Cash Flow Disclosures - MEC (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Income Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		$ 1,673	$ 1,764	$ 1,585
Income taxes received, net	[1]	1,016	1,666	635
Accruals related to property, plant and equipment additions		547	718	1,143
MidAmerican Energy Company [Member]
Condensed Income Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		181	154	144
Income taxes received, net		601	629	149
Accruals related to property, plant and equipment additions		131	249	128
Dividend, Noncash, Transfer Of Operations		$ 90	$ 0	$ 0
[1]	Includes $1.1 billion, $1.8 billion and $764 million of income taxes received from Berkshire Hathaway in 2016, 2015 and 2014, respectively.

Supplemental Cash Flow Discl206

Supplemental Cash Flow Disclosures - MidAmerican Funding (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		$ 1,673	$ 1,764	$ 1,585
Income taxes received, net	[1]	1,016	1,666	635
Accruals related to property, plant and equipment additions		547	718	1,143
MidAmerican Funding, LLC and Subsidiaries [Domain]
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		204	177	167
Income taxes received, net		609	630	153
Accruals related to property, plant and equipment additions		131	249	128
Dividend, Noncash, Transfer Of Operations		$ 90	$ 0	$ 0
[1]	Includes $1.1 billion, $1.8 billion and $764 million of income taxes received from Berkshire Hathaway in 2016, 2015 and 2014, respectively.

Supplemental Cash Flow Discl207

Supplemental Cash Flow Disclosures - NPC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized	$ 1,673	$ 1,764	$ 1,585
Accruals related to property, plant and equipment additions	547	718	1,143
Nevada Power Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized	173	186	194
Accruals related to property, plant and equipment additions	19	51	30
Capital and Financial Lease Obligations Incurred	$ (1)	$ (5)	$ 7

Supplemental Cash Flow Discl208

Supplemental Cash Flow Disclosures - SPPC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized	$ 1,673	$ 1,764	$ 1,585
Accruals related to property, plant and equipment additions	547	718	1,143
Sierra Pacific Power Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized	47	54	54
Accruals related to property, plant and equipment additions	15	24	31
Capital and Financial Lease Obligations Incurred	$ 0	$ 13	$ 1

Related Party Transactions - Pa

Related Party Transactions - PacifiCorp (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Related Party Transaction [Line Items]
Income Taxes Receivable From (Payable To) Related Parties Current	$ 27	$ 286
Related Party Transaction, Cash Received for Income Taxes, Net	1,100	1,800	$ 764
PacifiCorp [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	10	10	10
Due to Affiliate, Current	2	2
Related Party Transaction, Expense Reimbursement	4	7	10
Due from Affiliate, Current	1
PacifiCorp [Member] | Subsidiary of Common Parent [Member]
Related Party Transaction [Line Items]
Due to Affiliate, Current	1	1
Purchases from Related Party	7	8	7
Revenue from Related Parties	1	2	5
PacifiCorp [Member] | BNSF Railway Company [Member]
Related Party Transaction [Line Items]
Due to Affiliate, Current	1	1
Purchases from Related Party	37	39	39
PacifiCorp [Member] | MEHC Insurance Services Ltd. [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Proceeds From Insurance Claims	0	2	0
PacifiCorp [Member] | BHE [Member]
Related Party Transaction [Line Items]
Income Taxes Receivable From (Payable To) Related Parties Current	17	17
Related Party Transaction, Cash Received for Income Taxes, Net	(201)	(40)	(161)
PacifiCorp [Member] | Bridger Coal Company [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expense Reimbursement	2	19	3
Due from Affiliate, Current	5	4
PacifiCorp [Member] | Equity Method Investee [Member]
Related Party Transaction [Line Items]
Due to Affiliate, Current	17	16
Purchases from Related Party	$ 174	$ 181	$ 146

Related Party Transactions R210

Related Party Transactions Related Party Transactions - MEC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Related Party Transaction [Line Items]
Income Taxes Receivable From (Payable To) Related Parties Current	$ 27	$ 286
Related Party Transaction, Cash Received for Income Taxes, Net	1,100	1,800	$ 764
MidAmerican Energy Company [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expense Reimbursement	41	46	58
Due from Affiliate, Current	5	5
Due to Affiliate, Current	13	13
Due from Affiliate, Noncurrent	12	10
Due to Affiliate, Noncurrent	36	29
MidAmerican Energy Company [Member] | BHE [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	6	7	8
Income Taxes Receivable From (Payable To) Related Parties Current	(6)	102
Related Party Transaction, Cash Received for Income Taxes, Net	601	629	149
MidAmerican Energy Company [Member] | Northern Natural Gas and BNSF Railway Company [Member]
Related Party Transaction [Line Items]
Purchases from Related Party	$ 135	$ 165	$ 144

Related Party Transactions - Mi

Related Party Transactions - MidAmerican Funding (Details) $ in Millions		12 Months Ended
		Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Related Party Transaction [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,345	$ 6,421
Income Taxes Receivable From (Payable To) Related Parties Current		27	286
Related Party Transaction, Cash Received for Income Taxes, Net		1,100	1,800	$ 764
MidAmerican Funding, LLC and Subsidiaries [Domain]
Related Party Transaction [Line Items]
Notes Payable, Related Parties, Current		$ 31	139
Maximum Debt to Capitalization Ratio		0.67
Minumum Interest Coverage Ratio		2.2
MidAmerican Funding, LLC and Subsidiaries [Domain] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expense Reimbursement		$ 35	35	37
Due from Affiliate, Current		7	7
Due to Affiliate, Current		12	12
Due from Affiliate, Noncurrent		12	10
Due to Affiliate, Noncurrent		36	29
MidAmerican Funding, LLC and Subsidiaries [Domain] | BHE [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party		6	7	8
Income Taxes Receivable From (Payable To) Related Parties Current		(7)	102
Related Party Transaction, Cash Received for Income Taxes, Net		609	631	154
MidAmerican Funding, LLC and Subsidiaries [Domain] | Northern Natural Gas and BNSF Railway Company [Member]
Related Party Transaction [Line Items]
Purchases from Related Party		135	165	$ 144
MidAmerican Funding, LLC and Subsidiaries [Domain] | Revolving Credit Arrangement, $300 million [Member] | Line of Credit [Member] | MHC, Inc. [Member] | BHE [Member]
Related Party Transaction [Line Items]
Line of Credit Arrangement Offered to Affiliate, Maximum Amount Available		300
Notes Payable, Related Parties, Current		$ 31	$ 139
Debt, Weighted Average Interest Rate		0.885%	0.494%
MidAmerican Funding, LLC and Subsidiaries [Domain] | Revolving Credit Arrangement, $100 million [Member] | Line of Credit [Member] | MHC, Inc. [Member] | BHE [Member]
Related Party Transaction [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 100
Notes Receivable, Related Parties, Current		$ 0	$ 0
[1]	The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.

Related Party Transactions - NP

Related Party Transactions - NPC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Related Party Transaction [Line Items]
Income Taxes Receivable From (Payable To) Related Parties Current	$ 27	$ 286
Related Party Transaction, Cash Received for Income Taxes, Net	1,100	1,800	$ 764
Nevada Power Company [Member] | Kern River [Member]
Related Party Transaction [Line Items]
Purchases from Related Party		68	68
Nevada Power Company [Member] | Sierra Pacific Power Company [Member]
Related Party Transaction [Line Items]
Due from Affiliates		6
Due to Affiliate	0	0
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party		16	16
Related Party Transaction, Expense Reimbursement	24
Nevada Power Company [Member] | NV Energy, Inc. [Member]
Related Party Transaction [Line Items]
Due from Affiliates	0	0
Due to Affiliate	32
Related Party Transaction, Expense Reimbursement	1	1	1
Nevada Power Company [Member] | BHE [Member]
Related Party Transaction [Line Items]
Income Taxes Receivable From (Payable To) Related Parties Current	68	0
Related Party Transaction, Cash Received for Income Taxes, Net	0	0	0
Nevada Power Company [Member] | Electric Distribution [Member] | PacifiCorp [Member]
Related Party Transaction [Line Items]
Purchases from Related Party	0	2
Due from Affiliates	0	0
Due to Affiliate		0
Nevada Power Company [Member] | Electric Distribution [Member] | Sierra Pacific Power Company [Member]
Related Party Transaction [Line Items]
Purchases from Related Party	17
Revenue from Related Parties		69	$ 33
Due from Affiliates		15
Due to Affiliate	$ 12	$ 1

Related Party Transactions - SP

Related Party Transactions - SPPC (Details) - Sierra Pacific Power Company [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
NV Energy, Inc. [Member]
Related Party Transaction [Line Items]
Due from Affiliates	$ 0	$ 0
Due to Affiliate	18	21
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	5	6	$ 9
Nevada Power Company [Member]
Related Party Transaction [Line Items]
Due from Affiliates	0	0
Due to Affiliate	4	6
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	24	22	20
Related Party Transaction, Expense Reimbursement	14	16	16
Electric Distribution [Member] | Nevada Power Company [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	17	2	8
Purchases from Related Party	78	69	$ 33
Due from Affiliates	12	1
Due to Affiliate	$ 45	$ 15

Employee Benefit Plans - Net Pe

Employee Benefit Plans - Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	May 31, 2015
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	$ 7	$ 2
Defined Benefit Plan, Service Cost	29	33	$ 36
Defined Benefit Plan, Interest Cost	126	121	131
Defined Benefit Plan, Expected Return on Plan Assets	(160)	(169)	(164)
Defined Benefit Plan Net Amortization	46	53	44
Defined Benefit Plan, Net Periodic Benefit Cost	41	38	47
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	(7)	(8)
Defined Benefit Plan, Service Cost	9	11	14
Defined Benefit Plan, Interest Cost	31	31	46
Defined Benefit Plan, Expected Return on Plan Assets	(41)	(45)	(53)
Defined Benefit Plan Net Amortization	(12)	(11)	(3)
Defined Benefit Plan, Net Periodic Benefit Cost	(13)	(14)	4
UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	20	24	24
Defined Benefit Plan, Interest Cost	72	79	95
Defined Benefit Plan, Expected Return on Plan Assets	(110)	(116)	(124)
Defined Benefit Plan Net Amortization	44	62	51
Defined Benefit Plan, Net Periodic Benefit Cost	26	49	46
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	10	12	14
Defined Benefit Plan, Interest Cost	34	32	35
Defined Benefit Plan, Expected Return on Plan Assets	(44)	(46)	(45)
Defined Benefit Plan Net Amortization	2	2	1
Defined Benefit Plan, Net Periodic Benefit Cost	2	0	5
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	5	7	6
Defined Benefit Plan, Interest Cost	10	9	10
Defined Benefit Plan, Expected Return on Plan Assets	(13)	(15)	(15)
Defined Benefit Plan Net Amortization	(4)	(3)	(3)
Defined Benefit Plan, Net Periodic Benefit Cost	(2)	(2)	(2)
MidAmerican Energy Company [Member] | MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	(2)	(4)	1
MidAmerican Energy Company [Member] | MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	$ (1)	$ 0	$ 0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax				$ 9

Employee Benefit Plans - Funded

Employee Benefit Plans - Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2015
Domestic Pension Plans [Member]
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Fair Value of Plan Assets	$ 2,489	$ 2,718	$ 2,718	$ 2,525	$ 2,489
Defined Benefit Plan, Benefit Obligation	2,934	3,119	3,119	2,952	2,934
Defined Benefit Plan, Funded Status of Plan				(427)	(445)
Other assets				26	7
Other current liabilities				(15)	(15)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(438)	(437)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(427)	(445)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	2,489	2,718
Defined Benefit Plan, Contributions by Employer	78	13
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actual Return on Plan Assets	163	(17)
Defined Benefit Plan, Settlements, Plan Assets	(11)	23
Defined Benefit Plan, Benefits Paid	(194)	(202)
Ending balance	2,525	2,489	2,718
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	2,934	3,119
Defined Benefit Plan, Service Cost	29	33	36
Defined Benefit Plan, Interest Cost	126	121	131
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actuarial Gain (Loss)	67	(110)
Defined Benefit Plan, Plan Amendments	1	(4)
Defined Benefit Plan, Settlements, Benefit Obligation	(11)	(23)
Benefits Paid	(194)	(202)
Ending balance	2,952	2,934	3,119
Defined Benefit Plan, Accumulated Benefit Obligation				2,929	2,906
Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets [Abstract]
Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets				1,841	1,811
Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets, Aggregate Benefit Obligation				2,294	2,263
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation				2,278	2,244
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Fair Value of Plan Assets	662	858	858	666	662
Defined Benefit Plan, Benefit Obligation	740	936	936	734	740
Defined Benefit Plan, Funded Status of Plan				(68)	(78)
Other assets				19	15
Other current liabilities				0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(87)	(93)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(68)	(78)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	662	858
Defined Benefit Plan, Contributions by Employer	2	2
Defined Benefit Plan, Contributions by Plan Participants	10	9
Defined Benefit Plan, Actual Return on Plan Assets	41	0
Defined Benefit Plan, Settlements, Plan Assets	0	150
Defined Benefit Plan, Benefits Paid	(49)	(57)
Ending balance	666	662	858
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	740	936
Defined Benefit Plan, Service Cost	9	11	14
Defined Benefit Plan, Interest Cost	31	31	46
Defined Benefit Plan, Contributions by Plan Participants	10	9
Defined Benefit Plan, Actuarial Gain (Loss)	(7)	(43)
Defined Benefit Plan, Plan Amendments	0	3
Defined Benefit Plan, Settlements, Benefit Obligation	0	(150)
Benefits Paid	(49)	(57)
Ending balance	734	740	936
Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets [Abstract]
Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets				413	413
Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets, Aggregate Benefit Obligation				500	505
UK Pension Plans [Member]
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Fair Value of Plan Assets	2,276	2,368	2,368	2,169	2,276
Defined Benefit Plan, Benefit Obligation	2,142	2,279	2,279	2,125	2,142
Defined Benefit Plan, Funded Status of Plan				44	134
Other assets				44	134
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	2,276	2,368
Defined Benefit Plan, Contributions by Employer	55	77
Defined Benefit Plan, Contributions by Plan Participants	1	2
Defined Benefit Plan, Actual Return on Plan Assets	349	48
Defined Benefit Plan, Benefits Paid	(115)	(91)
Foreign Currency Exchange Rate Changes	(397)	(128)
Ending balance	2,169	2,276	2,368
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	2,142	2,279
Defined Benefit Plan, Service Cost	20	24	24
Defined Benefit Plan, Interest Cost	72	79	95
Defined Benefit Plan, Contributions by Plan Participants	1	2
Defined Benefit Plan, Actuarial Gain (Loss)	387	(30)
Benefits Paid	(115)	(91)
Foreign currency exchange rate changes	(382)	(121)
Ending balance	$ 2,125	$ 2,142	$ 2,279
Defined Benefit Plan, Accumulated Benefit Obligation				1,858	1,891
Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount				$ 242	$ 228

Employee Benefit Plans - Unreco

Employee Benefit Plans - Unrecognized Amounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	$ 19
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Gains (Losses), Net	35
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	19
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	(1)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	15
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax			$ 775	$ 768
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax			(7)	(25)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax			(7)	(2)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	741	$ 723	761	741
Beginning balance	741	723
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	65	75
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	3	(4)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(46)	(53)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	20	18
Ending balance	761	741
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Gains (Losses), Net	33
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	3	(4)
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	(2)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	28
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax			88	97
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax			(52)	(68)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax			7	8
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	37	23	43	37
Beginning balance	37	23
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(6)	0
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	16	3
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	12	11
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	6	14
Ending balance	43	37
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Gains (Losses), Net	2
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	16	3
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	1
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	(13)
UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax			590	592
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Gains (Losses), Net	65
Regulatory Asset, Pension and Other Postretirement Costs [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	729	710	761	729
Beginning balance	729	710
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	76	76
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	1	(4)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(45)	(53)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	32	19
Ending balance	761	729
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	1	(4)
Regulatory Asset, Pension and Other Postretirement Costs [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	49	37	55	49
Beginning balance	49	37
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(5)	(1)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net		3
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	11	10
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	6	12
Ending balance	55	49
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net		3
Regulatory Liability, Pension and Other Postretirement Costs [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	(1)	(6)	(13)	(1)
Beginning balance	(1)	(6)
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(11)	5
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	0	0
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(1)	0
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(12)	5
Ending balance	(13)	(1)
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	0	0
Regulatory Liability, Pension and Other Postretirement Costs [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	(12)	(14)	(12)	(12)
Beginning balance	(12)	(14)
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(1)	1
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net		0
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	1	1
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	0	2
Ending balance	(12)	(12)
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net		0
Accumulated Other Comprehensive Income (Loss) [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	13	19	13	13
Beginning balance	13	19
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	0	(6)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	0	0
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	0	0
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	0	(6)
Ending balance	13	13
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	0	0
Accumulated Other Comprehensive Income (Loss) [Member] | UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	592	655	$ 590	$ 592
Beginning balance	592	655
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	148	38
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(44)	(62)
Foreign currency exchange rate changes	(106)	(39)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(2)	(63)
Ending balance	590	$ 592
Defined Benefit Plan Amount Not Yet Recognized In Net Periodic Benefit Cost, Category [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	1
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	$ 1

Employee Benefit Plans - Plan A

Employee Benefit Plans - Plan Assumptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.40%	7.70%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	5.00%	5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate	2,025	2,025
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components	$ 1
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components	0
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	4
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	$ (4)
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.06%	4.43%	4.00%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.75%	2.75%	2.75%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.43%	4.00%	4.81%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.78%	6.88%	6.86%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.75%	2.75%	3.00%
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.01%	4.33%	3.88%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.33%	3.93%	4.82%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.03%	7.00%	7.34%
UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	2.70%	3.70%	3.60%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	3.00%	2.90%	2.80%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Expected Rate Of Future Price Inflation	3.00%	2.90%	2.80%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.70%	3.60%	4.40%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	5.60%	5.60%	6.10%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.90%	2.80%	3.15%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Rate of Future Price Inflation	2.90%	2.80%	3.15%

Employee Benefit Plans - Contri

Employee Benefit Plans - Contributions and Benefit Payments (Details) - 12 months ended Dec. 31, 2016 £ in Millions, $ in Millions	USD ($)	GBP (£)
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	$ 14
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	219
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	226
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	224
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	221
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	214
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	1,002
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	4
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	56
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	57
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	57
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	60
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	57
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	259
UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year | £		£ 37
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	75
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	77
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	79
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	81
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	83
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	$ 448

Employee Benefit Plans - Asset

Employee Benefit Plans - Asset Allocations (Details)		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Domestic Pension Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of Investment Funds Comprised Of Debt Securities		38.00%	34.00%
Percentage of Investment Funds Comprised Of Equity Securitites		62.00%	66.00%
Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of Investment Funds Comprised Of Debt Securities		37.00%	63.00%
Percentage of Investment Funds Comprised Of Equity Securitites		63.00%	37.00%
UK Pension Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of Investment Funds Comprised Of Debt Securities		56.00%
Percentage of Investment Funds Comprised Of Equity Securitites		44.00%
UK Pension Plans [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		50.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		55.00%
UK Pension Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		35.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		40.00%
UK Pension Plans [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		5.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		15.00%
PacifiCorp [Member] | Domestic Pension Plans [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	33.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	37.00%
PacifiCorp [Member] | Domestic Pension Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	53.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	57.00%
PacifiCorp [Member] | Domestic Pension Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		8.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		12.00%
PacifiCorp [Member] | Domestic Pension Plans [Member] | Other Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		0.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		1.00%
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	33.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	37.00%
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	61.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	65.00%
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		1.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		3.00%
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Other Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		0.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		1.00%
MidAmerican Energy Company [Member] | Domestic Pension Plans [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	20.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	40.00%
MidAmerican Energy Company [Member] | Domestic Pension Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	60.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	80.00%
MidAmerican Energy Company [Member] | Domestic Pension Plans [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		2.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		8.00%
MidAmerican Energy Company [Member] | Domestic Pension Plans [Member] | Other Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		0.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		5.00%
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	25.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	45.00%
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	50.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	80.00%
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		0.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		0.00%
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Other Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum		0.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum		5.00%
NV Energy, Inc. [Member] | Domestic Pension Plans [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	53.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	77.00%
NV Energy, Inc. [Member] | Domestic Pension Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	23.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	47.00%
NV Energy, Inc. [Member] | Domestic Other Postretirement Plans [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	4000.00%
NV Energy, Inc. [Member] | Domestic Other Postretirement Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	6000.00%
[1]	For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.

Employee Benefit Plans - Fair V

Employee Benefit Plans - Fair Value Measurements (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014	Dec. 31, 2013
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Actual Return on Plan Assets		$ 41		$ 0
Defined Benefit Plan, Settlements, Plan Assets		0		(150)
Defined Benefit Plan, Fair Value of Plan Assets		666		662		$ 858
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	411		401
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	95		103
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		20	[2]	13
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	18	[2]	12
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	2	[2]	1
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0	[2]	0
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		19		18
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	19		18
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		29		33
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	29		33
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		39		41
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	39		41
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		25		28
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	25		28
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		217		216
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	217		216
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5		6
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	5		6
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	$ 152		$ 149
Percentage of Investment Funds Comprised Of Equity Securitites		63.00%		37.00%
Percentage of Investment Funds Comprised Of Debt Securities		37.00%		63.00%
Percentage Of Investment Funds Invested in United States Securities		72.00%		70.00%
Percentage Of Investment Funds Invested In International Securities		28.00%		30.00%
Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[3]	$ 152		$ 149
Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[3]	0		0
Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[3]	0		0
Domestic Other Postretirement Plans [Member] | Plan Asset Categories Excluding Investments Measured with a NAV excluding the Practical Expedient [Domain]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		506		504
UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Actual Return on Plan Assets		349		48
Defined Benefit Plan, Fair Value of Plan Assets		2,169		2,276		2,368
UK Pension Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]	722		494
UK Pension Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]	1,178		1,388
UK Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]	105		204
UK Pension Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		87		46
UK Pension Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]	4		46
UK Pension Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]	83		0
UK Pension Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]	0		0
UK Pension Plans [Member] | United Kingdom Government Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		718		424
UK Pension Plans [Member] | United Kingdom Government Obligations [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		718	[4]	424
UK Pension Plans [Member] | United Kingdom Government Obligations [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0	[4]	0
UK Pension Plans [Member] | United Kingdom Government Obligations [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0	[4]	0
UK Pension Plans [Member] | Foreign Government Debt, Excluding That Of The United Kingdom [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				13
UK Pension Plans [Member] | Foreign Government Debt, Excluding That Of The United Kingdom [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]			0
UK Pension Plans [Member] | Foreign Government Debt, Excluding That Of The United Kingdom [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]			13
UK Pension Plans [Member] | Foreign Government Debt, Excluding That Of The United Kingdom [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]			0
UK Pension Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				186
UK Pension Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]			0
UK Pension Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]			186
UK Pension Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]			0
UK Pension Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[5]	$ 1,095		1,213
Percentage of Investment Funds Comprised Of Equity Securitites		44.00%
Percentage of Investment Funds Comprised Of Debt Securities		56.00%
UK Pension Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4],[5]	$ 0		24
UK Pension Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4],[5]	1,095		1,189
UK Pension Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4],[5]	0		0
UK Pension Plans [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		105		204
UK Pension Plans [Member] | Real Estate Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]	0		0
UK Pension Plans [Member] | Real Estate Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]	0		0
UK Pension Plans [Member] | Real Estate Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		105	[4]	204	[4]	$ 199	$ 179
UK Pension Plans [Member] | Plan Asset Categories Excluding Investments Measured with a NAV excluding the Practical Expedient [Domain]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,005		2,086
Accounting Standards Update 2015-07 [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		666		662
Accounting Standards Update 2015-07 [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	156		154
Accounting Standards Update 2015-07 [Member] | Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	4		4
Accounting Standards Update 2015-07 [Member] | UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,169		2,276
Accounting Standards Update 2015-07 [Member] | UK Pension Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[5]	$ 164		$ 190
[1]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[2]	Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
[3]	Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 63% and 37%, respectively, for both 2016 and 2015. Additionally, these funds are invested in United States and international securities of approximately 72% and 28%, respectively, for 2016 and 70% and 30%, respectively, for 2015.
[4]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[5]	Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 44% and 56%, respectively, for both 2016 and 2015.

Employee Benefit Plans - Level

Employee Benefit Plans - Level 3 Rollforward (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Domestic Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		$ 2,489		$ 2,718
Ending balance		2,525		2,489		$ 2,718
Domestic Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	[1]	0
Ending balance	[1]	0		0
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		662		858
Ending balance		666		662		858
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	[2]	0
Ending balance	[2]	0		0
UK Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		2,276		2,368
Foreign Currency Exchange Rate Changes		(397)		(128)
Ending balance		2,169		2,276		2,368
UK Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	[3]	204
Ending balance	[3]	105		204
UK Pension Plans [Member] | Real Estate Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		204
Ending balance		105		204
UK Pension Plans [Member] | Real Estate Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		204	[3]	199		179
Defined Benefit Plan, Actual Return on Plan Assets Still Held		10		18		33
Defined Benefit Plan, Purchases, Sales, and Settlements		(80)		0		0
Foreign Currency Exchange Rate Changes		(29)		(13)		(13)
Ending balance		$ 105	[3]	$ 204	[3]	$ 199
[1]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[2]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[3]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.

Employee Benefit Plans - Define

Employee Benefit Plans - Defined Contribution Plans (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Contribution Plan, Cost Recognized	$ 102	$ 90	$ 83
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	$ (7)	$ (8)

Employee Benefit Plans - Pacifi

Employee Benefit Plans - PacifiCorp - Utah Mine Disposition and Labor Agreement (Details) - Domestic Other Postretirement Plans [Member] - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	May 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	$ 7	$ 8
PacifiCorp [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Amount To Be Transferred	150		$ 150
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	$ 8	$ 9	$ 9

Employee Benefit Plans - Pac224

Employee Benefit Plans - PacifiCorp - Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	$ 29	$ 33	$ 36
Defined Benefit Plan, Interest Cost	126	121	131
Defined Benefit Plan, Expected Return on Plan Assets	(160)	(169)	(164)
Defined Benefit Plan Net Amortization	46	53	44
Defined Benefit Plan, Net Periodic Benefit Cost	41	38	47
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	9	11	14
Defined Benefit Plan, Interest Cost	31	31	46
Defined Benefit Plan, Expected Return on Plan Assets	(41)	(45)	(53)
Defined Benefit Plan Net Amortization	(12)	(11)	(3)
Defined Benefit Plan, Net Periodic Benefit Cost	(13)	(14)	4
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	4	4	5
Defined Benefit Plan, Interest Cost	54	53	57
Defined Benefit Plan, Expected Return on Plan Assets	(75)	(77)	(76)
Defined Benefit Plan Net Amortization	34	42	29
Defined Benefit Plan, Net Periodic Benefit Cost	17	22	15
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	2	3	6
Defined Benefit Plan, Interest Cost	15	16	28
Defined Benefit Plan, Expected Return on Plan Assets	(21)	(23)	(31)
Defined Benefit Plan Net Amortization	(5)	(4)	2
Defined Benefit Plan, Net Periodic Benefit Cost	$ (9)	$ (8)	$ 5

Employee Benefit Plans - Pac225

Employee Benefit Plans - PacifiCorp - Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	May 31, 2015
Domestic Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	$ 2,489	$ 2,718
Defined Benefit Plan, Contributions by Employer	78	13
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actual Return on Plan Assets	163	(17)
Defined Benefit Plan, Settlements, Plan Assets	11	(23)
Defined Benefit Plan, Benefits Paid	(194)	(202)
Ending balance	2,525	2,489	$ 2,718
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	2,934	3,119
Defined Benefit Plan, Service Cost	29	33	36
Defined Benefit Plan, Interest Cost	126	121	131
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actuarial Gain (Loss)	67	(110)
Defined Benefit Plan, Settlements, Benefit Obligation	(11)	(23)
Defined Benefit Plan, Benefits Paid	(194)	(202)
Defined Benefit Plan, Benefit Obligation	2,934	3,119	3,119	$ 2,952	$ 2,934
Defined Benefit Plan, Accumulated Benefit Obligation				2,929	2,906
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan				(427)	(445)
Other current liabilities				(15)	(15)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(438)	(437)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(427)	(445)
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	662	858
Defined Benefit Plan, Contributions by Employer	2	2
Defined Benefit Plan, Contributions by Plan Participants	10	9
Defined Benefit Plan, Actual Return on Plan Assets	41	0
Defined Benefit Plan, Settlements, Plan Assets	0	(150)
Defined Benefit Plan, Benefits Paid	(49)	(57)
Ending balance	666	662	858
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	740	936
Defined Benefit Plan, Service Cost	9	11	14
Defined Benefit Plan, Interest Cost	31	31	46
Defined Benefit Plan, Contributions by Plan Participants	10	9
Defined Benefit Plan, Actuarial Gain (Loss)	(7)	(43)
Defined Benefit Plan, Settlements, Benefit Obligation	0	(150)
Defined Benefit Plan, Benefits Paid	(49)	(57)
Defined Benefit Plan, Benefit Obligation	740	936	936	734	740
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan				(68)	(78)
Other current liabilities				0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(87)	(93)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(68)	(78)
Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount				242	228
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	1,043	1,146
Defined Benefit Plan, Contributions by Employer	5	4
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actual Return on Plan Assets	51	0
Defined Benefit Plan, Settlements, Plan Assets	0	0
Defined Benefit Plan, Benefits Paid	(100)	(107)
Ending balance	999	1,043	1,146
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	1,289	1,378
Defined Benefit Plan, Service Cost	4	4	5
Defined Benefit Plan, Interest Cost	54	53	57
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actuarial Gain (Loss)	29	(39)
Defined Benefit Plan, Settlements, Benefit Obligation	0	0
Defined Benefit Plan, Benefits Paid	(100)	(107)
Defined Benefit Plan, Benefit Obligation	1,289	1,378	1,378	1,276	1,289
Defined Benefit Plan, Accumulated Benefit Obligation				1,276	1,289
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan				(277)	(246)
Other current liabilities				(5)	(4)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(272)	(242)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(277)	(246)
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	305	482
Defined Benefit Plan, Contributions by Employer	1	1
Defined Benefit Plan, Contributions by Plan Participants	6	6
Defined Benefit Plan, Actual Return on Plan Assets	17	1
Defined Benefit Plan, Settlements, Plan Assets	0	(150)
Defined Benefit Plan, Benefits Paid	(27)	(35)
Ending balance	302	305	482
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	362	539
Defined Benefit Plan, Service Cost	2	3	6
Defined Benefit Plan, Interest Cost	15	16	28
Defined Benefit Plan, Contributions by Plan Participants	6	6
Defined Benefit Plan, Actuarial Gain (Loss)	0	(17)
Defined Benefit Plan, Settlements, Benefit Obligation	0	(150)
Defined Benefit Plan, Benefits Paid	(27)	(35)
Defined Benefit Plan, Benefit Obligation	$ 362	$ 539	$ 539	358	362
Defined Benefit Plan, Amount To Be Transferred				150		$ 150
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan				(56)	(57)
Other current liabilities				0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(56)	(57)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(56)	(57)
PacifiCorp [Member] | Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount				$ 55	$ 52

Employee Benefit Plans - Pac226

Employee Benefit Plans - PacifiCorp - Unrecognized Amounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	May 31, 2015	Dec. 31, 2014
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Gains (Losses), Net	$ 35
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(19)
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	(1)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	15
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax	775	$ 768
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(7)	(25)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	(7)	(2)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	761	741		$ 723
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	65	75
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(46)	(53)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	20	18
Defined Benefit Plan, Amortization of Gains (Losses), Net	33
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(3)	4
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	(2)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	28
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax	88	97
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(52)	(68)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	7	8
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	43	37		23
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(6)	0
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	12	11
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	6	14
Defined Benefit Plan, Amortization of Gains (Losses), Net	2
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(16)	(3)
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	1
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	(13)
Regulatory Asset, Pension and Other Postretirement Costs [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	761	729		710
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	76	76
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(45)	(53)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	32	19
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(1)	4
Regulatory Asset, Pension and Other Postretirement Costs [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	55	49		37
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(5)	(1)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	11	10
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	6	12
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net		(3)
Accumulated Other Comprehensive Income (Loss) [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	13	13		19
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	0	(6)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	0	0
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	0	(6)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	0	0
PacifiCorp [Member]
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Gains (Losses), Net	16
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(7)
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	(1)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	8
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax	518	508
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	0	(13)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	(7)	(3)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	511	492		496
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	53	38
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(34)	(42)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	19	(4)
Defined Benefit Plan, Amortization of Gains (Losses), Net	16
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	0
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	(2)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	14
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax	39	36
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(13)	(19)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	8	9	$ 9
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	34	26
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Gains (Losses), Net	0
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(7)
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	1
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	(6)
PacifiCorp [Member] | Regulatory Asset, Pension and Other Postretirement Costs [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	491	473		474
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	51	40
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(33)	(41)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	18	(1)
PacifiCorp [Member] | Regulatory Asset, Pension and Other Postretirement Costs [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	34	26		17
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	3	5
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	5	4
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	8	9
PacifiCorp [Member] | Accumulated Other Comprehensive Income (Loss) [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	20	19		$ 22
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	2	(2)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(1)	(1)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	$ 1	$ (3)

Employee Benefit Plans - Pac227

Employee Benefit Plans - PacifiCorp - Plan Assumptions (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.06%	4.43%	4.00%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.75%	2.75%	2.75%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.43%	4.00%	4.81%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.78%	6.88%	6.86%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.75%	2.75%	3.00%
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.01%	4.33%	3.88%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.33%	3.93%	4.82%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.03%	7.00%	7.34%
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.05%	4.40%	4.00%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase		2.75%	2.75%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.40%	4.00%	4.80%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.50%	7.50%	7.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.75%	2.75%	3.00%
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.05%	4.35%	3.90%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.35%	3.99%	4.90%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.50%	7.08%	7.50%

Employee Benefit Plans - Pac228

Employee Benefit Plans - PacifiCorp - Contributions and Benefit Payments (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	$ 14
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	219
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	226
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	224
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	221
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	214
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	1,002
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	4
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	56
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	57
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	57
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	60
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	57
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	259
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	5
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	105
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	109
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	108
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	104
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	97
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	426
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	0
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	28
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	28
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	27
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	30
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	26
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	$ 116

Employee Benefit Plans - Pac229

Employee Benefit Plans - PacifiCorp - Asset Allocations (Details) - PacifiCorp [Member]	12 Months Ended
	Dec. 31, 2016	[2]
Domestic Pension Plans [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	33.00%	[1]
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	37.00%	[1]
Domestic Pension Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	53.00%	[1]
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	57.00%	[1]
Domestic Pension Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	8.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	12.00%
Domestic Pension Plans [Member] | Other Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	0.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	1.00%
Domestic Other Postretirement Plans [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	33.00%	[1]
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	37.00%	[1]
Domestic Other Postretirement Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	61.00%	[1]
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	65.00%	[1]
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	1.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	3.00%
Domestic Other Postretirement Plans [Member] | Other Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	0.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	1.00%
[1]	For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.
[2]	PacifiCorp's Retirement Plan trust includes a separate account that is used to fund benefits for the other postretirement benefit plan. In addition to this separate account, the assets for the other postretirement benefit plan are held in Voluntary Employees' Beneficiary Association ("VEBA") trusts, each of which has its own investment allocation strategies. Target allocations for the other postretirement benefit plan include the separate account of the Retirement Plan trust and the VEBA trusts.

Employee Benefit Plans - Pac230

Employee Benefit Plans - PacifiCorp - Fair Value Measurements (Details) - USD ($) $ in Millions		Dec. 31, 2016		Dec. 31, 2015	Dec. 31, 2014
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 2,525		$ 2,489	$ 2,718
United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	1,011		1,007
United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	483		544
United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Plan Asset Categories Excluding Investments Measured with a NAV excluding the Practical Expedient [Domain]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,494		1,551
United States Pension Plan of US Entity [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		58		26
United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	4		0
United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	54		26
United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		161		155
United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	161		155
United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Foreign Government Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2		4
United States Pension Plan of US Entity [Member] | Foreign Government Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Foreign Government Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	2		4
United States Pension Plan of US Entity [Member] | Foreign Government Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		295		335
United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	295		335
United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		20		25
United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	20		25
United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		112		154
United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	112		154
United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		583		586
United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	583		586
United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		117		122
United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	117		122
United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	$ 146		$ 144
Percentage of Investment Funds Comprised Of Equity Securitites		62.00%		66.00%
Percentage of Investment Funds Comprised Of Debt Securities		38.00%		34.00%
Percentage Of Investment Funds Invested in United States Securities		60.00%		58.00%
Percentage Of Investment Funds Invested In International Securities		40.00%		42.00%
United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[2]	$ 146		$ 144
United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[2]	0		0
United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[2]	0		0
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		666		662	858
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	411		401
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	95		103
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Plan Asset Categories Excluding Investments Measured with a NAV excluding the Practical Expedient [Domain]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		506		504
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		20	[4]	13
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	18	[4]	12
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	2	[4]	1
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0	[4]	0
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		19		18
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	19		18
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		29		33
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	29		33
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		39		41
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	39		41
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		25		28
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	25		28
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		217		216
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	217		216
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5		6
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	5		6
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[5]	$ 152		$ 149
Percentage of Investment Funds Comprised Of Equity Securitites		63.00%		37.00%
Percentage of Investment Funds Comprised Of Debt Securities		37.00%		63.00%
Percentage Of Investment Funds Invested in United States Securities		72.00%		70.00%
Percentage Of Investment Funds Invested In International Securities		28.00%		30.00%
Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3],[5]	$ 152		$ 149
Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3],[5]	0		0
Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3],[5]	0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		999		1,043	1,146
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		512		527
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		89		100
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Plan Asset Categories Excluding Investments Measured with a NAV excluding the Practical Expedient [Domain]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		601		627
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		10		10
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		10		10
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		25		19
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		25		19
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		36		42
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		36		42
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		6		5
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		6		5
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		37		43
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		37		43
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		389		408
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		389		408
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		15		17
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		15		17
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 83		$ 83
Percentage of Investment Funds Comprised Of Equity Securitites		54.00%		53.00%
Percentage of Investment Funds Comprised Of Debt Securities		46.00%		47.00%
Percentage Of Investment Funds Invested in United States Securities		39.00%		40.00%
Percentage Of Investment Funds Invested In International Securities		61.00%		60.00%
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 83		$ 83
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		302		305	$ 482
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		144		144
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		29		31
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Plan Asset Categories Excluding Investments Measured with a NAV excluding the Practical Expedient [Domain]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		173		175
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5		5
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4		4
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1		1
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		11		9
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		11		9
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		13		15
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		13		15
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2		1
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2		1
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		13		14
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		13		14
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		93		95
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		93		95
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4		4
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4		4
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 32		$ 32
Percentage of Investment Funds Comprised Of Equity Securitites		62.00%		61.00%
Percentage of Investment Funds Comprised Of Debt Securities		38.00%		39.00%
Percentage Of Investment Funds Invested in United States Securities		71.00%		67.00%
Percentage Of Investment Funds Invested In International Securities		29.00%		33.00%
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 32		$ 32
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Accounting Standards Update 2015-07 [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,525		2,489
Accounting Standards Update 2015-07 [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	920		823
Accounting Standards Update 2015-07 [Member] | United States Pension Plan of US Entity [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[6]	61		65
Accounting Standards Update 2015-07 [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		666		662
Accounting Standards Update 2015-07 [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[5]	156		154
Accounting Standards Update 2015-07 [Member] | Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4]	4		4
Accounting Standards Update 2015-07 [Member] | PacifiCorp [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				1,043
Accounting Standards Update 2015-07 [Member] | PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[7]	337		351
Accounting Standards Update 2015-07 [Member] | PacifiCorp [Member] | United States Pension Plan of US Entity [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[8]	61		65
Accounting Standards Update 2015-07 [Member] | PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		302		305
Accounting Standards Update 2015-07 [Member] | PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[7]	125		126
Accounting Standards Update 2015-07 [Member] | PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[8]	$ 4		$ 4
[1]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[2]	Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 62% and 38%, respectively, for 2016 and 66% and 34%, respectively, for 2015. Additionally, these funds are invested in United States and international securities of approximately 60% and 40%, respectively, for 2016 and 58% and 42%, respectively, for 2015.
[3]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[4]	Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
[5]	Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 63% and 37%, respectively, for both 2016 and 2015. Additionally, these funds are invested in United States and international securities of approximately 72% and 28%, respectively, for 2016 and 70% and 30%, respectively, for 2015.
[6]	Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
[7]	Investment funds are substantially comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 54% and 46% respectively, for 2016 and 53% and 47%, respectively, for 2015, and are invested in United States and international securities of approximately 39% and 61%, respectively, for 2016 and 40% and 60%, respectively, for 2015.
[8]	Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.

Employee Benefit Plans - Pac231

Employee Benefit Plans - PacifiCorp - Multiemployer and Joint Trust Pension Plans (Details) - PacifiCorp [Member] - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014
Defined Benefit Plan Disclosure [Line Items]
Joint Trustee Plan, Percentage By Which Joint Trustee Plan was at Least Funded			80.00%		80.00%		80.00%
Joint Trustee Plan, Period Contributions	[1]	$ 8		$ 8		$ 9
UMWA Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Multiemployer Plans, Withdrawal Obligation, Most Recent Estimate		115
Multiemployer Plans, Certified Zone Status			Red		Red		Red
Multiemployer Plan, Period Contributions	[1]	$ 0		$ 1		$ 2
[1]	PacifiCorp's and Energy West Mining Company's minimum contributions to the plans are based on the amount of wages paid to employees covered by the Local 57 Trust Fund collective bargaining agreements and the number of mining hours worked for the UMWA 1974 Pension Plan, respectively, subject to ERISA minimum funding requirements. As a result of the plan's critical status, Energy West Mining Company was required to begin paying a surcharge for hours worked on and after December 1, 2014.

Employee Benefit Plans Employee

Employee Benefit Plans Employee Benefit Plans - PacifiCorp - Defined Contribution Plans (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	$ 102	$ 90	$ 83
PacifiCorp [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	$ 34	$ 35	$ 34

Employee Benefit Plans - MEC -

Employee Benefit Plans - MEC - Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	$ 29	$ 33	$ 36
Defined Benefit Plan, Interest Cost	126	121	131
Defined Benefit Plan, Expected Return on Plan Assets	(160)	(169)	(164)
Defined Benefit Plan Net Amortization	46	53	44
Defined Benefit Plan, Net Periodic Benefit Cost	41	38	47
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	9	11	14
Defined Benefit Plan, Interest Cost	31	31	46
Defined Benefit Plan, Expected Return on Plan Assets	(41)	(45)	(53)
Defined Benefit Plan Net Amortization	(12)	(11)	(3)
Defined Benefit Plan, Net Periodic Benefit Cost	(13)	(14)	4
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	10	12	14
Defined Benefit Plan, Interest Cost	34	32	35
Defined Benefit Plan, Expected Return on Plan Assets	(44)	(46)	(45)
Defined Benefit Plan Net Amortization	2	2	1
Defined Benefit Plan, Net Periodic Benefit Cost	2	0	5
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	5	7	6
Defined Benefit Plan, Interest Cost	10	9	10
Defined Benefit Plan, Expected Return on Plan Assets	(13)	(15)	(15)
Defined Benefit Plan Net Amortization	(4)	(3)	(3)
Defined Benefit Plan, Net Periodic Benefit Cost	(2)	(2)	(2)
MidAmerican Energy Company [Member] | MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	(2)	(4)	1
MidAmerican Energy Company [Member] | MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	$ (1)	$ 0	$ 0

Employee Benefit Plans - MEC234

Employee Benefit Plans - MEC - Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
United States Pension Plan of US Entity [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	$ 2,489	$ 2,718
Defined Benefit Plan, Contributions by Employer	78	13
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actual Return on Plan Assets	163	(17)
Defined Benefit Plan, Benefits Paid	(194)	(202)
Ending balance	2,525	2,489	$ 2,718
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	2,934	3,119
Defined Benefit Plan, Service Cost	29	33	36
Defined Benefit Plan, Interest Cost	126	121	131
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actuarial Gain (Loss)	67	(110)
Defined Benefit Plan, Benefits Paid	(194)	(202)
Ending balance	2,952	2,934	3,119
Defined Benefit Plan, Accumulated Benefit Obligation	2,929	2,906
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan	(427)	(445)
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	26	7
Other current liabilities	(15)	(15)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(438)	(437)
Defined Benefit Plan, Amounts Recognized in Balance Sheet	(427)	(445)
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	662	858
Defined Benefit Plan, Contributions by Employer	2	2
Defined Benefit Plan, Contributions by Plan Participants	10	9
Defined Benefit Plan, Actual Return on Plan Assets	41	0
Defined Benefit Plan, Benefits Paid	(49)	(57)
Ending balance	666	662	858
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	740	936
Defined Benefit Plan, Service Cost	9	11	14
Defined Benefit Plan, Interest Cost	31	31	46
Defined Benefit Plan, Contributions by Plan Participants	10	9
Defined Benefit Plan, Actuarial Gain (Loss)	(7)	(43)
Defined Benefit Plan, Benefits Paid	(49)	(57)
Ending balance	734	740	936
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan	(68)	(78)
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	19	15
Other current liabilities	0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(87)	(93)
Defined Benefit Plan, Amounts Recognized in Balance Sheet	(68)	(78)
Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount	242	228
MidAmerican Energy Company [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount	184	175
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	678	730
Defined Benefit Plan, Contributions by Employer	7	7
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actual Return on Plan Assets	57	4
Defined Benefit Plan, Benefits Paid	(58)	(63)
Ending balance	684	678	730
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	785	840
Defined Benefit Plan, Service Cost	10	12	14
Defined Benefit Plan, Interest Cost	34	32	35
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actuarial Gain (Loss)	2	(36)
Defined Benefit Plan, Benefits Paid	(58)	(63)
Ending balance	773	785	840
Defined Benefit Plan, Accumulated Benefit Obligation	764	773
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan	(89)	(107)
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	26	7
Other current liabilities	(8)	(8)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(107)	(106)
Defined Benefit Plan, Amounts Recognized in Balance Sheet	(89)	(107)
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	249	259
Defined Benefit Plan, Contributions by Employer	1	1
Defined Benefit Plan, Contributions by Plan Participants	1	1
Defined Benefit Plan, Actual Return on Plan Assets	14	0
Defined Benefit Plan, Benefits Paid	(13)	(12)
Ending balance	252	249	259
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	234	249
Defined Benefit Plan, Service Cost	5	7	6
Defined Benefit Plan, Interest Cost	10	9	10
Defined Benefit Plan, Contributions by Plan Participants	1	1
Defined Benefit Plan, Actuarial Gain (Loss)	(4)	(20)
Defined Benefit Plan, Benefits Paid	(13)	(12)
Ending balance	233	234	$ 249
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan	19	15
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	19	15
Other current liabilities	0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	0	0
Defined Benefit Plan, Amounts Recognized in Balance Sheet	19	15
BHE [Member] | MidAmerican Energy Company [Member] | Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount	166	156
MidAmerican Energy Company [Member] | MidAmerican Energy Company [Member] | Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount	$ 110	$ 104

Employee Benefit Plans - MEC235

Employee Benefit Plans - MEC - Unrecognized Amounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Gains (Losses), Net	$ 35
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(19)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	15
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax	775	$ 768
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(7)	(25)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	761	741	$ 723
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	65	75
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(46)	(53)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	20	18
Defined Benefit Plan, Amortization of Gains (Losses), Net	33
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(3)	4
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	28
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax	88	97
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(52)	(68)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	43	37	23
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(6)	0
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	12	11
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	6	14
Defined Benefit Plan, Amortization of Gains (Losses), Net	2
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(16)	(3)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	(13)
Regulatory Asset, Pension and Other Postretirement Costs [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	761	729	710
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	76	76
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(45)	(53)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	32	19
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(1)	4
Regulatory Asset, Pension and Other Postretirement Costs [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	55	49	37
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(5)	(1)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	11	10
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	6	12
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net		(3)
Regulatory Liability, Pension and Other Postretirement Costs [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	(13)	(1)	(6)
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(11)	5
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(1)	0
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(12)	5
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	0	0
Regulatory Liability, Pension and Other Postretirement Costs [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	(12)	(12)	(14)
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(1)	1
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	1	1
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	0	2
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net		0
MidAmerican Energy Company [Member]
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Amortization of Gains (Losses), Net	3
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(5)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	(2)
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax	15	26
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	1	2
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	16	28	24
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(10)	6
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(2)	(2)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(12)	4
Defined Benefit Plan, Amortization of Gains (Losses), Net	1
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	1
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	2
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Gains (Losses), Before Tax	36	42
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(31)	(36)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	5	6	7
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(5)	(5)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	4	4
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(1)	(1)
Defined Benefit Plan, Amortization of Gains (Losses), Net	2
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(6)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	(4)
MidAmerican Energy Company [Member] | Regulatory Asset, Pension and Other Postretirement Costs [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	22	22	22
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	1	2
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(1)	(2)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	0	0
MidAmerican Energy Company [Member] | Regulatory Asset, Pension and Other Postretirement Costs [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	18	17	20
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(2)	(5)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	3	2
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	1	(3)
MidAmerican Energy Company [Member] | Regulatory Liability, Pension and Other Postretirement Costs [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	(12)	0	(5)
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(11)	5
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(1)	0
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(12)	5
MidAmerican Energy Company [Member] | Regulatory Liability, Pension and Other Postretirement Costs [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	0	0	0
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	0	0
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	0	0
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	0	0
MidAmerican Energy Company [Member] | Receivables (Payables) With Affiliates [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	6	6	7
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	0	(1)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	0	0
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	0	(1)
MidAmerican Energy Company [Member] | Receivables (Payables) With Affiliates [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	(13)	(11)	$ (13)
Defined Benefit Plan, Reconciliation of Amounts Not Yet Recognized As Components of Net Periodic Benefit Cost [Roll Forward]
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(3)	0
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	1	2
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	$ (2)	$ 2

Employee Benefit Plans - MEC236

Employee Benefit Plans - MEC - Plan Assumptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.40%	7.70%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	5.00%	5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate	2,025	2,025
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components	$ 1
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components	0
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	4
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	$ (4)
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.06%	4.43%	4.00%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.75%	2.75%	2.75%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.43%	4.00%	4.81%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.78%	6.88%	6.86%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.75%	2.75%	3.00%
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.01%	4.33%	3.88%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.33%	3.93%	4.82%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.03%	7.00%	7.34%
MidAmerican Energy Company [Member] | United States Non-Union Postretirement Benefit Plans of US Entity, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	5.00%	5.18%	5.37%
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.10%	4.50%	4.00%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.75%	2.75%	2.75%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.50%	4.00%	4.75%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.00%	7.25%	7.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.75%	2.75%	3.00%
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.90%	4.25%	3.75%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.25%	3.75%	4.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.75%	7.00%	7.25%
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.40%	7.70%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	5.00%	5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate	2,025	2,025
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components	$ 0
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components	0
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	3
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	$ (2)

Employee Benefit Plans - MEC237

Employee Benefit Plans - MEC - Contributions and Benefit Payments (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	$ 14
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	219
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	226
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	224
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	221
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	214
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	1,002
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	4
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	56
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	57
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	57
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	60
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	57
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	259
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	8
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	60
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	60
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	62
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	62
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	60
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	278
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	1
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	18
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	19
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	20
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	21
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	21
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	$ 97

Employee Benefit Plans - MEC238

Employee Benefit Plans - MEC - Asset Allocations (Details) - MidAmerican Energy Company [Member]	12 Months Ended
	Dec. 31, 2016
United States Pension Plan of US Entity [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	20.00%	[1]
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	40.00%	[1]
United States Pension Plan of US Entity [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	60.00%	[1]
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	80.00%	[1]
United States Pension Plan of US Entity [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	2.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	8.00%
United States Pension Plan of US Entity [Member] | Other Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	0.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	5.00%
Domestic Other Postretirement Plans [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	25.00%	[1]
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	45.00%	[1]
Domestic Other Postretirement Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	50.00%	[1]
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	80.00%	[1]
Domestic Other Postretirement Plans [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	0.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	0.00%
Domestic Other Postretirement Plans [Member] | Other Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	0.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	5.00%
[1]	(1)For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.

Employee Benefit Plans - MEC239

Employee Benefit Plans - MEC - Fair Value Measurements (Details) - USD ($) $ in Millions		Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 2,525		$ 2,489		$ 2,718
United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	1,011		1,007
United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	483		544
United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		58		26
United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	4		0
United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	54		26
United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		161		155
United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	161		155
United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		295		335
United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	295		335
United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		20		25
United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	20		25
United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		112		154
United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	112		154
United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		583		586
United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	583		586
United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		117		122
United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	117		122
United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
United States Pension Plan of US Entity [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	$ 146		$ 144
Percentage of Investment Funds Comprised Of Equity Securitites		62.00%		66.00%
Percentage of Investment Funds Comprised Of Debt Securities		38.00%		34.00%
Percentage Of Investment Funds Invested in United States Securities		60.00%		58.00%
Percentage Of Investment Funds Invested In International Securities		40.00%		42.00%
United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[2]	$ 146		$ 144
United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[2]	0		0
United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[2]	0		0
United States Pension Plan of US Entity [Member] | Plan Asset Categories Excluding Investments Measured with a NAV excluding the Practical Expedient [Domain]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,494		1,551
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		666		662		858
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	411		401
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	95		103
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		20	[4]	13
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	18	[4]	12
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	2	[4]	1
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0	[4]	0
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		19		18
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	19		18
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		29		33
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	29		33
Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		39		41
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	39		41
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		25		28
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	25		28
Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		217		216
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	217		216
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5		6
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	5		6
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[5]	$ 152		$ 149
Percentage of Investment Funds Comprised Of Equity Securitites		63.00%		37.00%
Percentage of Investment Funds Comprised Of Debt Securities		37.00%		63.00%
Percentage Of Investment Funds Invested in United States Securities		72.00%		70.00%
Percentage Of Investment Funds Invested In International Securities		28.00%		30.00%
Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3],[5]	$ 152		$ 149
Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3],[5]	0		0
Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3],[5]	0		0
Domestic Other Postretirement Plans [Member] | Plan Asset Categories Excluding Investments Measured with a NAV excluding the Practical Expedient [Domain]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		506		504
Accounting Standards Update 2015-07 [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,525		2,489
Accounting Standards Update 2015-07 [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	920		823
Accounting Standards Update 2015-07 [Member] | United States Pension Plan of US Entity [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		50		50
Accounting Standards Update 2015-07 [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		666		662
Accounting Standards Update 2015-07 [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[5]	156		154
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		684		678		730
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		241		236
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		98		106
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		17		16
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		17		16
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		9		5
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		9		5
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		53		57
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		53		57
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		6		6
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		6		6
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		22		27
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		22		27
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		130		130
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		130		130
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		39		40
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		39		40
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Foreign Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[6]	$ 63		$ 61
Percentage of Investment Funds Comprised Of Equity Securitites		74.00%		72.00%
Percentage of Investment Funds Comprised Of Debt Securities		26.00%		28.00%
Percentage Of Investment Funds Invested in United States Securities		71.00%		73.00%
Percentage Of Investment Funds Invested In International Securities		29.00%		27.00%
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[6]	$ 63		$ 61
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member] | Plan Asset Categories Excluding Investments Measured with a NAV excluding the Practical Expedient [Domain]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		339		342
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		252		249		$ 259
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		193		186
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		59		63
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		10		5
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		10		5
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5		5
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5		5
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		11		12
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		11		12
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Corporate Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		37		39
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		37		39
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		11		12
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		11		12
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		122		120
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		122		120
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Domestic Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[7]	$ 56		$ 56
Percentage of Investment Funds Comprised Of Equity Securitites		70.00%		68.00%
Percentage of Investment Funds Comprised Of Debt Securities		30.00%		32.00%
Percentage Of Investment Funds Invested in United States Securities		30.00%		32.00%
Percentage Of Investment Funds Invested In International Securities		70.00%		68.00%
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[7]	$ 56		$ 56
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[7]	0		0
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member] | Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[7]	0		0
MidAmerican Energy Company [Member] | Accounting Standards Update 2015-07 [Member] | United States Pension Plan of US Entity [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		295	[8]	296	[6]
MidAmerican Energy Company [Member] | Accounting Standards Update 2015-07 [Member] | United States Pension Plan of US Entity [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 50		$ 40
[1]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[2]	Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 62% and 38%, respectively, for 2016 and 66% and 34%, respectively, for 2015. Additionally, these funds are invested in United States and international securities of approximately 60% and 40%, respectively, for 2016 and 58% and 42%, respectively, for 2015.
[3]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[4]	Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
[5]	Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 63% and 37%, respectively, for both 2016 and 2015. Additionally, these funds are invested in United States and international securities of approximately 72% and 28%, respectively, for 2016 and 70% and 30%, respectively, for 2015.
[6]	(2)Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 74% and 26%, respectively, for 2016 and 72% and 28%, respectively, for 2015. Additionally, these funds are invested in United States and international securities of approximately 71% and 29%, respectively, for 2016 and 73% and 27%, respectively, for 2015.
[7]	(2)Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 70% and 30%, respectively, for 2016 and 68% and 32%, respectively, for 2015. Additionally, these funds are invested in United States and international securities of approximately 30% and 70%, respectively, for 2016 and 32% and 68%, respectively, for 2015.
[8]	(1)For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.

Employee Benefit Plans - MEC240

Employee Benefit Plans - MEC - Level 3 Rollforward (Details) - United States Pension Plan of US Entity [Member] - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 2,525	$ 2,489	$ 2,718
Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0	0
MidAmerican Energy Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		684	678	$ 730
MidAmerican Energy Company [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 0	$ 0
[1]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.

Employee Benefit Plans - MEC241

Employee Benefit Plans - MEC - Defined Contribution Plans (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	$ 102	$ 90	$ 83
MidAmerican Energy Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	$ 20	$ 20	$ 19

Employee Benefit Plans - MidAme

Employee Benefit Plans - MidAmerican Funding - Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	$ 41	$ 38	$ 47
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	(13)	(14)	4
MidAmerican Funding, LLC and Subsidiaries [Domain] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	4	4	4
MidAmerican Funding, LLC and Subsidiaries [Domain] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	$ (1)	$ (2)	$ (2)

Retirement Plan and Postreti243

Retirement Plan and Postretirement Benefits - NPC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
United States Pension Plan of US Entity [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	$ (438)	$ (437)
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	15	15
Defined Benefit Plan, Contributions by Employer	78	13
Nevada Power Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Contributions by Employer	36	0	$ 0
Nevada Power Company [Member] | Nonqualified Pension Plans [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Contributions by Employer	0	0	0
Nevada Power Company [Member] | Other Postretirement Benefit Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Contributions by Employer	0	0	$ 0
Nevada Power Company [Member] | NV Energy, Inc. [Member] | Other Noncurrent Liabilities [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(24)	(38)
Nevada Power Company [Member] | NV Energy, Inc. [Member] | Other Noncurrent Liabilities [Member] | Nonqualified Pension Plans [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(9)	(9)
Nevada Power Company [Member] | NV Energy, Inc. [Member] | Other Noncurrent Liabilities [Member] | Other Postretirement Benefit Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(4)	(5)
Nevada Power Company [Member] | NV Energy, Inc. [Member] | Other Current Liabilities [Member] | Nonqualified Pension Plans [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	$ 1	$ 1

Retirement Plan and Postreti244

Retirement Plan and Postretirement Benefits - SPPC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
United States Pension Plan of US Entity [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Contributions by Employer	$ 78	$ 13
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(438)	(437)
Other current liabilities	(15)	(15)
Sierra Pacific Power Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Contributions by Employer	27	0	$ 0
Sierra Pacific Power Company [Member] | Nonqualified Pension Plans [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Contributions by Employer	0	0	0
Sierra Pacific Power Company [Member] | Other Postretirement Benefit Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Contributions by Employer	1	0	$ 0
Sierra Pacific Power Company [Member] | Other Noncurrent Liabilities [Member] | NV Energy, Inc. [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(12)	(29)
Sierra Pacific Power Company [Member] | Other Noncurrent Liabilities [Member] | NV Energy, Inc. [Member] | Nonqualified Pension Plans [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(9)	(9)
Sierra Pacific Power Company [Member] | Other Noncurrent Liabilities [Member] | NV Energy, Inc. [Member] | Other Postretirement Benefit Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(28)	(32)
Sierra Pacific Power Company [Member] | Other Current Liabilities [Member] | NV Energy, Inc. [Member] | Nonqualified Pension Plans [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Other current liabilities	$ (1)	$ (1)

Asset Retirement Obligations -

Asset Retirement Obligations - Asset Retirement Obligation By Type (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		$ 954	$ 921	$ 753
Regulatory Liabilities		3,120	3,033
Fossil Fuel Plant [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		404	443
Quad Cities Station [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		343	289
Wind Generating Facility [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		124	104
Offshore pipeline facilities [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		33	31
Solar Generating Facility [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		12	12
Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		38	42
Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[1]	2,242	2,167
Quad Cities Station nuclear decommissioning trust funds [Member]
Asset Retirement Obligations By Type [Line Items]
Nuclear decommissioning trust funds		$ 460	$ 429
[1]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.

Asset Retirement Obligations246

Asset Retirement Obligations - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 921	$ 753
Asset Retirement Obligation, Revision of Estimate	33	104
Asset Retirement Obligation, Liabilities Incurred	25	59
Retirements	(63)	(32)
Asset Retirement Obligation, Accretion Expense	38	37
Asset Retirement Obligation	921	753	$ 954	$ 921
Asset Retirement Obligation, Current			98	92
Asset Retirement Obligations, Noncurrent			$ 856	$ 829
Ending Balance	$ 954	$ 921

Asset Retirement Obligations247

Asset Retirement Obligations - PacifiCorp - Asset Retirement Obligations By Type (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligations By Type [Line Items]
Regulatory liabilities	$ 2,933	$ 2,631
PacifiCorp [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory liabilities	978	938
PacifiCorp [Member] | Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory liabilities	$ 917	$ 894

Asset Retirement Obligations248

Asset Retirement Obligations - PacifiCorp - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 921	$ 753
Asset Retirement Obligation, Revision of Estimate	33	104
Asset Retirement Obligation, Liabilities Incurred	25	59
Retirements	(63)	(32)
Asset Retirement Obligation, Accretion Expense	38	37
Asset Retirement Obligation	921	753	$ 954	$ 921
Asset Retirement Obligation, Current			98	92
Asset Retirement Obligations, Noncurrent			856	829
Ending Balance	954	921
PacifiCorp [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	224	135
Asset Retirement Obligation, Revision of Estimate	2	62
Asset Retirement Obligation, Liabilities Incurred	0	30
Retirements	(19)	(10)
Asset Retirement Obligation, Accretion Expense	8	7
Asset Retirement Obligation	224	135	215	224
Asset Retirement Obligation, Current			21	35
Asset Retirement Obligations, Noncurrent			$ 194	$ 189
Ending Balance	$ 215	$ 224

Asset Retirement Obligations249

Asset Retirement Obligations - MEC - Asset Retirement Obligations By Type (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		$ 954	$ 921	$ 753
Regulatory Liabilities		3,120	3,033
Quad Cities Unit Nos 1 and 2 [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		343	289
Fossil Fuel Plant [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		404	443
Wind Generating Facility [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		124	104
Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		38	42
MidAmerican Energy Company [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		567	532	$ 460
Decommissioning Fund Investments, Fair Value		460	429
MidAmerican Energy Company [Member] | Quad Cities Unit Nos 1 and 2 [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		343	289
MidAmerican Energy Company [Member] | Fossil Fuel Plant [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		132	160
MidAmerican Energy Company [Member] | Wind Generating Facility [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		91	82
MidAmerican Energy Company [Member] | Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		1	1
Quad Cities Unit Nos 1 and 2 [Member] | MidAmerican Energy Company [Member]
Asset Retirement Obligations By Type [Line Items]
Decommissioning Fund Investments, Fair Value		460	429
Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[1]	2,242	2,167
Removal Costs [Member] | MidAmerican Energy Company [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities		$ 665	$ 653
[1]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.

Asset Retirement Obligations250

Asset Retirement Obligations - MEC - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 921	$ 753
Asset Retirement Obligation, Revision of Estimate	33	104
Asset Retirement Obligation, Liabilities Incurred	25	59
Asset Retirement Obligation, Liabilities Settled	(63)	(32)
Asset Retirement Obligation, Accretion Expense	38	37
Asset Retirement Obligation, Current	98	92
Asset Retirement Obligations, Noncurrent	856	829
Ending Balance	954	921
MidAmerican Energy Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	532	460
Asset Retirement Obligation, Revision of Estimate	28	36
Asset Retirement Obligation, Liabilities Incurred	14	22
Asset Retirement Obligation, Liabilities Settled	(32)	(9)
Asset Retirement Obligation, Accretion Expense	25	23
Asset Retirement Obligation, Current	57	44
Asset Retirement Obligations, Noncurrent	510	488
Ending Balance	$ 567	$ 532

Asset Retirement Obligations251

Asset Retirement Obligations - NPC - Asset Retirement Obligation by Type (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities		$ 3,120	$ 3,033
Asset Retirement Obligation		954	921	$ 753
Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		38	42
Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[1]	2,242	2,167
Nevada Power Company [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities		453	477
Asset Retirement Obligation		83	85	$ 86
Nevada Power Company [Member] | Waste water remediation [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		38	42
Nevada Power Company [Member] | Evaporative Ponds and Dry Ash Landfills [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		22	27
Nevada Power Company [Member] | Asbestos [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		4	3
Nevada Power Company [Member] | Solar [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		2	2
Nevada Power Company [Member] | Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		17	11
Nevada Power Company [Member] | Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[2]	$ 294	$ 273
[1]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
[2]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.

Asset Retirement Obligations As

Asset Retirement Obligations Asset Retirement Obligations - NPC - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 921	$ 753
Asset Retirement Obligation, Revision of Estimate	33	104
Asset Retirement Obligation, Liabilities Incurred	25	59
Retirements	(63)	(32)
Asset Retirement Obligation, Accretion Expense	38	37
Ending Balance	954	921
Asset Retirement Obligation, Current	98	92
Asset Retirement Obligations, Noncurrent	856	829
Nevada Power Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	85	86
Asset Retirement Obligation, Revision of Estimate	4	3
Asset Retirement Obligation, Liabilities Incurred	0	3
Retirements	(10)	(11)
Asset Retirement Obligation, Accretion Expense	4	4
Ending Balance	83	85
Asset Retirement Obligation, Current	20	13
Asset Retirement Obligations, Noncurrent	$ 63	$ 72

Asset Retirement Obligations253

Asset Retirement Obligations - SPPC - Asset Retirement Obligation by Type (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities		$ 3,120	$ 3,033
Asset Retirement Obligation		954	921	$ 753
Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		38	42
Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[1]	2,242	2,167
Sierra Pacific Power Company [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities		290	308
Asset Retirement Obligation		10	10	$ 11
Sierra Pacific Power Company [Member] | Asbestos [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		4	4
Sierra Pacific Power Company [Member] | Evaporative Ponds and Dry Ash Landfills [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		3	3
Sierra Pacific Power Company [Member] | Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		3	3
Sierra Pacific Power Company [Member] | Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[2]	$ 205	$ 208
[1]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
[2]	Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.

Asset Retirement Obligations254

Asset Retirement Obligations - SPPC - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 921	$ 753
Asset Retirement Obligation, Revision of Estimate	33	104
Retirements	(63)	(32)
Asset Retirement Obligation, Accretion Expense	38	37
Ending Balance	954	921
Asset Retirement Obligation, Current	98	92
Asset Retirement Obligations, Noncurrent	856	829
Sierra Pacific Power Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	10	11
Retirements	0	(1)
Ending Balance	10	10
Asset Retirement Obligation, Current	0	0
Asset Retirement Obligations, Noncurrent	$ 10	$ 10

Commitments and Contingencies -

Commitments and Contingencies - Commitments Table (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)number_of_projects	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Contractual Obligation [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 141
Operating Leases, Future Minimum Payments, Due in Two Years	122
Operating Leases, Future Minimum Payments, Due in Three Years	101
Operating Leases, Future Minimum Payments, Due in Four Years	87
Operating Leases, Future Minimum Payments, Due in Five Years	73
Operating Leases, Future Minimum Payments, Due Thereafter	1,085
Operating Leases, Future Minimum Payments Due	1,609
Contractual Obligation, Due in Next Twelve Months	3,666
Contractual Obligation, Due in Second Year	1,997
Contractual Obligation, Due in Third Year	1,768
Contractual Obligation, Due in Fourth Year	1,482
Contractual Obligation, Due in Fifth Year	1,264
Contractual Obligation, Due after Fifth Year	11,865
Contractual Obligation	22,042
Operating Leases, Rent Expense	156	$ 161	$ 146
MidAmerican Funding [Member]
Contractual Obligation [Line Items]
Coal transportation costs, railroad	$ 137	$ 185	$ 159
Number of Construction Projects | number_of_projects	2
Fuel, capacity and transmission contract commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	$ 2,370
Purchase Obligation, Due in Second Year	1,606
Purchase Obligation, Due in Third Year	1,389
Purchase Obligation, Due in Fourth Year	1,208
Purchase Obligation, Due in Fifth Year	1,010
Purchase Obligation, Due after Fifth Year	10,053
Purchase Obligation	17,636
Capital Addition Purchase Commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	852
Purchase Obligation, Due in Second Year	49
Purchase Obligation, Due in Third Year	66
Purchase Obligation, Due in Fourth Year	1
Purchase Obligation, Due in Fifth Year	1
Purchase Obligation, Due after Fifth Year	4
Purchase Obligation	973
Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	303
Purchase Obligation, Due in Second Year	220
Purchase Obligation, Due in Third Year	212
Purchase Obligation, Due in Fourth Year	186
Purchase Obligation, Due in Fifth Year	180
Purchase Obligation, Due after Fifth Year	723
Purchase Obligation	$ 1,824

Commitments and Contingencies _

Commitments and Contingencies – Hydroelectric (Details)	12 Months Ended
	Dec. 31, 2016USD ($)
PacifiCorp [Member]
Hydroelectric [Line Items]
Capital expenditures required by hydroelectric licenses	$ 227,000,000
PacifiCorp [Member] | Klamath Hydroelectric System [Member]
Hydroelectric [Line Items]
Dam removal cost limit	200,000,000
PacifiCorp [Member] | Klamath Hydroelectric System [Member] | OREGON
Hydroelectric [Line Items]
Dam removal cost limit	184,000,000
PacifiCorp [Member] | Klamath Hydroelectric System [Member] | CALIFORNIA
Hydroelectric [Line Items]
Dam removal cost limit	16,000,000
Additional dam removal costs, California bond measure	250,000,000
PacifiCorp [Member] | Klamath Hydroelectric System [Member] | VARIOUS [Domain]
Hydroelectric [Line Items]
Klamath Relicensing and Settlement Costs	68,000,000
PacifiCorp [Member]
Hydroelectric [Line Items]
Capital expenditures required by hydroelectric licenses	227,000,000
PacifiCorp [Member] | Klamath Hydroelectric System [Member]
Hydroelectric [Line Items]
Dam removal cost limit	200,000,000
Public Utilities Property Plant & Equipment, Number of Generating Facilities	4
PacifiCorp [Member] | Klamath Hydroelectric System [Member] | OREGON
Hydroelectric [Line Items]
Dam removal cost limit	184,000,000
PacifiCorp [Member] | Klamath Hydroelectric System [Member] | CALIFORNIA
Hydroelectric [Line Items]
Dam removal cost limit	16,000,000
Additional dam removal costs, California bond measure	$ 250,000,000

Commitments and Contingencie257

Commitments and Contingencies - PacifiCorp - Hydroelectric (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Hydroelectric [Line Items]
Assets	$ 85,440	$ 83,618	$ 81,816
PacifiCorp [Member]
Hydroelectric [Line Items]
Assets	22,394	$ 22,367
Capital expenditures required by hydroelectric licenses	227
PacifiCorp [Member] | Klamath Hydroelectric System [Member]
Hydroelectric [Line Items]
Dam removal cost limit	200
PacifiCorp [Member] | Klamath Hydroelectric System [Member] | OREGON
Hydroelectric [Line Items]
Dam removal cost limit	184
PacifiCorp [Member] | Klamath Hydroelectric System [Member] | CALIFORNIA
Hydroelectric [Line Items]
Dam removal cost limit	16
Additional dam removal costs, California bond measure	250
PacifiCorp [Member] | Klamath Hydroelectric System [Member] | VARIOUS [Domain]
Hydroelectric [Line Items]
Klamath Relicensing and Settlement Costs	$ 68

Commitments and Contingencie258

Commitments and Contingencies - PacifiCorp - Commitments Tables (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Contractual Obligation [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 141
Operating Leases, Future Minimum Payments, Due in Two Years	122
Operating Leases, Future Minimum Payments, Due in Three Years	101
Operating Leases, Future Minimum Payments, Due in Four Years	87
Operating Leases, Future Minimum Payments, Due in Five Years	73
Operating Leases, Future Minimum Payments, Due Thereafter	1,085
Operating Leases, Future Minimum Payments Due	1,609
Contractual Obligation, Due in Next Twelve Months	3,666
Contractual Obligation, Due in Second Year	1,997
Contractual Obligation, Due in Third Year	1,768
Contractual Obligation, Due in Fourth Year	1,482
Contractual Obligation, Due in Fifth Year	1,264
Contractual Obligation, Due after Fifth Year	11,865
Contractual Obligation	22,042
Capital Addition Purchase Commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	852
Purchase Obligation, Due in Second Year	49
Purchase Obligation, Due in Third Year	66
Purchase Obligation, Due in Fourth Year	1
Purchase Obligation, Due in Fifth Year	1
Purchase Obligation, Due after Fifth Year	4
Purchase Obligation	973
Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	303
Purchase Obligation, Due in Second Year	220
Purchase Obligation, Due in Third Year	212
Purchase Obligation, Due in Fourth Year	186
Purchase Obligation, Due in Fifth Year	180
Purchase Obligation, Due after Fifth Year	723
Purchase Obligation	1,824
PacifiCorp [Member]
Contractual Obligation [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	5
Operating Leases, Future Minimum Payments, Due in Two Years	5
Operating Leases, Future Minimum Payments, Due in Three Years	5
Operating Leases, Future Minimum Payments, Due in Four Years	5
Operating Leases, Future Minimum Payments, Due in Five Years	4
Operating Leases, Future Minimum Payments, Due Thereafter	39
Operating Leases, Future Minimum Payments Due	63
Contractual Obligation, Due in Next Twelve Months	1,288
Contractual Obligation, Due in Second Year	975
Contractual Obligation, Due in Third Year	922
Contractual Obligation, Due in Fourth Year	768
Contractual Obligation, Due in Fifth Year	581
Contractual Obligation, Due after Fifth Year	4,005
Contractual Obligation	8,539
Rent expense for power purchase agreements meeting definition of operating lease	$ 14	$ 13	$ 15
Maximum percentage of energy sources for which a share of operating costs and debt service is required	5.00%	5.00%	5.00%
Operating leases, rent expense, net	$ 15	$ 15	$ 16
PacifiCorp [Member] | Purchased electricity contracts - commercially operable
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	253
Purchase Obligation, Due in Second Year	160
Purchase Obligation, Due in Third Year	157
Purchase Obligation, Due in Fourth Year	157
Purchase Obligation, Due in Fifth Year	145
Purchase Obligation, Due after Fifth Year	1,630
Purchase Obligation	2,502
PacifiCorp [Member] | Purchased electricity contracts - not commercially operable
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	10
Purchase Obligation, Due in Second Year	13
Purchase Obligation, Due in Third Year	17
Purchase Obligation, Due in Fourth Year	17
Purchase Obligation, Due in Fifth Year	18
Purchase Obligation, Due after Fifth Year	390
Purchase Obligation	465
PacifiCorp [Member] | Fuel contracts
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	796
Purchase Obligation, Due in Second Year	616
Purchase Obligation, Due in Third Year	596
Purchase Obligation, Due in Fourth Year	507
Purchase Obligation, Due in Fifth Year	346
Purchase Obligation, Due after Fifth Year	1,407
Purchase Obligation	4,268
PacifiCorp [Member] | Capital Addition Purchase Commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	62
Purchase Obligation, Due in Second Year	46
Purchase Obligation, Due in Third Year	26
Purchase Obligation, Due in Fourth Year	4
Purchase Obligation, Due in Fifth Year	1
Purchase Obligation, Due after Fifth Year	4
Purchase Obligation	143
PacifiCorp [Member] | Transmission
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	109
Purchase Obligation, Due in Second Year	106
Purchase Obligation, Due in Third Year	90
Purchase Obligation, Due in Fourth Year	61
Purchase Obligation, Due in Fifth Year	47
Purchase Obligation, Due after Fifth Year	467
Purchase Obligation	880
PacifiCorp [Member] | Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	53
Purchase Obligation, Due in Second Year	29
Purchase Obligation, Due in Third Year	31
Purchase Obligation, Due in Fourth Year	17
Purchase Obligation, Due in Fifth Year	20
Purchase Obligation, Due after Fifth Year	68
Purchase Obligation	$ 218

Commitments and Contingencie259

Commitments and Contingencies - MEC - Commitments Table (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)number_of_projects	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Contractual Obligation [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 141
Operating Leases, Future Minimum Payments, Due in Two Years	122
Operating Leases, Future Minimum Payments, Due in Three Years	101
Operating Leases, Future Minimum Payments, Due in Four Years	87
Operating Leases, Future Minimum Payments, Due in Five Years	73
Operating Leases, Future Minimum Payments, Due Thereafter	1,085
Operating Leases, Future Minimum Payments Due	1,609
Contractual Obligation, Due in Next Twelve Months	3,666
Contractual Obligation, Due in Second Year	1,997
Contractual Obligation, Due in Third Year	1,768
Contractual Obligation, Due in Fourth Year	1,482
Contractual Obligation, Due in Fifth Year	1,264
Contractual Obligation, Due after Fifth Year	11,865
Contractual Obligation	22,042
Capital Addition Purchase Commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	852
Purchase Obligation, Due in Second Year	49
Purchase Obligation, Due in Third Year	66
Purchase Obligation, Due in Fourth Year	1
Purchase Obligation, Due in Fifth Year	1
Purchase Obligation, Due after Fifth Year	4
Purchase Obligation	973
Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	303
Purchase Obligation, Due in Second Year	220
Purchase Obligation, Due in Third Year	212
Purchase Obligation, Due in Fourth Year	186
Purchase Obligation, Due in Fifth Year	180
Purchase Obligation, Due after Fifth Year	723
Purchase Obligation	1,824
MidAmerican Energy Company [Member]
Contractual Obligation [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	20
Operating Leases, Future Minimum Payments, Due in Two Years	20
Operating Leases, Future Minimum Payments, Due in Three Years	20
Operating Leases, Future Minimum Payments, Due in Four Years	19
Operating Leases, Future Minimum Payments, Due in Five Years	19
Operating Leases, Future Minimum Payments, Due Thereafter	624
Operating Leases, Future Minimum Payments Due	722
Contractual Obligation, Due in Next Twelve Months	754
Contractual Obligation, Due in Second Year	248
Contractual Obligation, Due in Third Year	198
Contractual Obligation, Due in Fourth Year	151
Contractual Obligation, Due in Fifth Year	140
Contractual Obligation, Due after Fifth Year	916
Contractual Obligation	$ 2,407
Number of Construction Projects | number_of_projects	2
Operating leases, rent expense, net	$ 4	$ 4	$ 4
MidAmerican Energy Company [Member] | Fuel contracts
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	141
Purchase Obligation, Due in Second Year	73
Purchase Obligation, Due in Third Year	40
Purchase Obligation, Due in Fourth Year	0
Purchase Obligation, Due in Fifth Year	0
Purchase Obligation, Due after Fifth Year	0
Purchase Obligation	254
MidAmerican Energy Company [Member] | Electric capacity and transmission
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	37
Purchase Obligation, Due in Second Year	29
Purchase Obligation, Due in Third Year	29
Purchase Obligation, Due in Fourth Year	28
Purchase Obligation, Due in Fifth Year	25
Purchase Obligation, Due after Fifth Year	59
Purchase Obligation	207
MidAmerican Energy Company [Member] | Natural gas contracts for gas operations
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	137
Purchase Obligation, Due in Second Year	34
Purchase Obligation, Due in Third Year	13
Purchase Obligation, Due in Fourth Year	12
Purchase Obligation, Due in Fifth Year	10
Purchase Obligation, Due after Fifth Year	23
Purchase Obligation	229
MidAmerican Energy Company [Member] | Capital Addition Purchase Commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	347
Purchase Obligation, Due in Second Year	2
Purchase Obligation, Due in Third Year	5
Purchase Obligation, Due in Fourth Year	0
Purchase Obligation, Due in Fifth Year	0
Purchase Obligation, Due after Fifth Year	0
Purchase Obligation	354
MidAmerican Energy Company [Member] | Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	72
Purchase Obligation, Due in Second Year	90
Purchase Obligation, Due in Third Year	91
Purchase Obligation, Due in Fourth Year	92
Purchase Obligation, Due in Fifth Year	86
Purchase Obligation, Due after Fifth Year	210
Purchase Obligation	$ 641

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies - MEC - Transmission Rates (Details) - MidAmerican Energy Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Unfavorable Regulatory Action [Member]
Loss Contingencies [Line Items]
Loss Contingency Accrual	$ 10
Electric Transmission [Member]
Loss Contingencies [Line Items]
Public Utilities, Approved Return on Equity Adder, Percentage	0.50%
Electric Transmission [Member] | Prior to September 2016 [Member]
Loss Contingencies [Line Items]
Public Utilities, Approved Return on Equity, Percentage	12.38%
Electric Transmission [Member] | November 2013 to February 2015 [Member]
Loss Contingencies [Line Items]
Public Utilities, Approved Return on Equity, Percentage	10.32%
Public Utilities, Intervenor Proposed Return On Equity, Percentage	9.15%
Electric Transmission [Member] | February 2015 through May 2016 [Member]
Loss Contingencies [Line Items]
Public Utilities, Intervenor Proposed Return On Equity, Percentage	8.67%

Commitments and Contingencie261

Commitments and Contingencies - NPC - Legal (Details) - Nevada Power Company [Member]	1 Months Ended		12 Months Ended
	Jun. 30, 2016MW	Feb. 29, 2016MW	Dec. 31, 2016MW	Dec. 31, 2015power_purchase_agreementsMW	Dec. 31, 2014MW
Loss Contingencies [Line Items]
Number of Approved Renewable Power Purchase Agreements | power_purchase_agreements				2
812 Megawatts of Coal Energy [Member]
Loss Contingencies [Line Items]
Coal-Fired Power Plant Capacity			812
130 Megawatts of Natural Gas Energy [Member]
Loss Contingencies [Line Items]
New Generation Capacity			130
272 Megawatts of Renewable Energy [Member]
Loss Contingencies [Line Items]
New Generation Capacity					272
210 Megawatts of Renewable Energy [Member]
Loss Contingencies [Line Items]
New Generation Capacity					210
15 Megawatts of Solar Renewable Energy [Member]
Loss Contingencies [Line Items]
New Generation Capacity				15
100 Megawatts of Renewable Energy [Member]
Loss Contingencies [Line Items]
New Generation Capacity	100			100
35 Megawatts of Renewable Energy [Member]
Loss Contingencies [Line Items]
New Generation Capacity		35

Commitments and Contingencie262

Commitments and Contingencies - NPC - Commitments Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Contractual Obligation [Line Items]
Contractual Obligation, Due in Next Twelve Months	$ 3,666
Contractual Obligation, Due in Second Year	1,997
Contractual Obligation, Due in Third Year	1,768
Contractual Obligation, Due in Fourth Year	1,482
Contractual Obligation, Due in Fifth Year	1,264
Contractual Obligation, Due after Fifth Year	11,865
Contractual Obligation	22,042
Operating Leases, Rent Expense	156	$ 161	$ 146
Fuel, capacity and transmission contract commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	2,370
Purchase Obligation, Due in Second Year	1,606
Purchase Obligation, Due in Third Year	1,389
Purchase Obligation, Due in Fourth Year	1,208
Purchase Obligation, Due in Fifth Year	1,010
Purchase Obligation, Due after Fifth Year	10,053
Purchase Obligation	17,636
Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	303
Purchase Obligation, Due in Second Year	220
Purchase Obligation, Due in Third Year	212
Purchase Obligation, Due in Fourth Year	186
Purchase Obligation, Due in Fifth Year	180
Purchase Obligation, Due after Fifth Year	723
Purchase Obligation	1,824
Nevada Power Company [Member]
Contractual Obligation [Line Items]
Contractual Obligation, Due in Next Twelve Months	831
Contractual Obligation, Due in Second Year	507
Contractual Obligation, Due in Third Year	426
Contractual Obligation, Due in Fourth Year	435
Contractual Obligation, Due in Fifth Year	438
Contractual Obligation, Due after Fifth Year	6,119
Contractual Obligation	8,756
Rent expense for power purchase agreements meeting definition of operating lease	302	264	245
Operating Leases, Rent Expense	13	$ 11	$ 10
Nevada Power Company [Member] | Fuel, capacity and transmission contract commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	697
Purchase Obligation, Due in Second Year	445
Purchase Obligation, Due in Third Year	352
Purchase Obligation, Due in Fourth Year	355
Purchase Obligation, Due in Fifth Year	358
Purchase Obligation, Due after Fifth Year	5,310
Purchase Obligation	7,517
Nevada Power Company [Member] | Fuel, capacity and transmission contract commitments, Not commercially operable
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	7
Purchase Obligation, Due in Second Year	14
Purchase Obligation, Due in Third Year	29
Purchase Obligation, Due in Fourth Year	36
Purchase Obligation, Due in Fifth Year	37
Purchase Obligation, Due after Fifth Year	683
Purchase Obligation	806
Nevada Power Company [Member] | Operating Leases and easements [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	9
Purchase Obligation, Due in Second Year	9
Purchase Obligation, Due in Third Year	8
Purchase Obligation, Due in Fourth Year	7
Purchase Obligation, Due in Fifth Year	7
Purchase Obligation, Due after Fifth Year	51
Purchase Obligation	91
Nevada Power Company [Member] | Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	118
Purchase Obligation, Due in Second Year	39
Purchase Obligation, Due in Third Year	37
Purchase Obligation, Due in Fourth Year	37
Purchase Obligation, Due in Fifth Year	36
Purchase Obligation, Due after Fifth Year	75
Purchase Obligation	$ 342

Commitments and Contingencie263

Commitments and Contingencies - SPPC - Legal (Details)	Dec. 31, 2016
Idaho Power Company [Member] | Valmy Generating Station [Member]
Loss Contingencies [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%

Commitments and Contingencie264

Commitments and Contingencies - SPPC - Commitments Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Contractual Obligation [Line Items]
Contractual Obligation, Due in Next Twelve Months	$ 3,666
Contractual Obligation, Due in Second Year	1,997
Contractual Obligation, Due in Third Year	1,768
Contractual Obligation, Due in Fourth Year	1,482
Contractual Obligation, Due in Fifth Year	1,264
Contractual Obligation, Due after Fifth Year	11,865
Contractual Obligation	22,042
Operating Leases, Rent Expense	156	$ 161	$ 146
Fuel, capacity and transmission contract commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	2,370
Purchase Obligation, Due in Second Year	1,606
Purchase Obligation, Due in Third Year	1,389
Purchase Obligation, Due in Fourth Year	1,208
Purchase Obligation, Due in Fifth Year	1,010
Purchase Obligation, Due after Fifth Year	10,053
Purchase Obligation	17,636
Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	303
Purchase Obligation, Due in Second Year	220
Purchase Obligation, Due in Third Year	212
Purchase Obligation, Due in Fourth Year	186
Purchase Obligation, Due in Fifth Year	180
Purchase Obligation, Due after Fifth Year	723
Purchase Obligation	1,824
Sierra Pacific Power Company [Member]
Contractual Obligation [Line Items]
Contractual Obligation, Due in Next Twelve Months	251
Contractual Obligation, Due in Second Year	175
Contractual Obligation, Due in Third Year	120
Contractual Obligation, Due in Fourth Year	91
Contractual Obligation, Due in Fifth Year	82
Contractual Obligation, Due after Fifth Year	653
Contractual Obligation	1,372
Rent expense for power purchase agreements meeting definition of operating lease	69	65	68
Operating Leases, Rent Expense	6	$ 7	$ 6
Sierra Pacific Power Company [Member] | Fuel, capacity and transmission contract commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	238
Purchase Obligation, Due in Second Year	156
Purchase Obligation, Due in Third Year	103
Purchase Obligation, Due in Fourth Year	71
Purchase Obligation, Due in Fifth Year	62
Purchase Obligation, Due after Fifth Year	375
Purchase Obligation	1,005
Sierra Pacific Power Company [Member] | Operating Leases, Easements, Maintenance and Service [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	4
Purchase Obligation, Due in Second Year	4
Purchase Obligation, Due in Third Year	3
Purchase Obligation, Due in Fourth Year	3
Purchase Obligation, Due in Fifth Year	3
Purchase Obligation, Due after Fifth Year	46
Purchase Obligation	63
Sierra Pacific Power Company [Member] | Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	4
Purchase Obligation, Due in Second Year	5
Purchase Obligation, Due in Third Year	4
Purchase Obligation, Due in Fourth Year	6
Purchase Obligation, Due in Fifth Year	6
Purchase Obligation, Due after Fifth Year	17
Purchase Obligation	$ 42

Preferred Stock - PacifiCorp (D

Preferred Stock - PacifiCorp (Details) - PacifiCorp [Member] shares in Thousands	12 Months Ended
	Dec. 31, 2016Payments$ / sharesshares	Dec. 31, 2015$ / sharesshares
Class of Stock [Line Items]
Number Of Full Quarterly Dividend Payments In Default Before Preferred Stockholders Elect Board Of Directors | Payments	4
Preferred Stock Class, Serial Preferred [Member]
Class of Stock [Line Items]
Preferred Stock, Shares Authorized	3,500	3,500
Preferred Stock, Par or Stated Value Per Share | $ / shares	$ 100	$ 100
Preferred Stock, Shares Issued	24	24
Preferred Stock, Shares Outstanding	24	24
Preferred Stock Class, No Par Serial Preferred [Member]
Class of Stock [Line Items]
Shares Authorized for Certain Class of Preferred Stock	16,000	16,000
Shares Issued for Certain Class of Preferred Stock	0	0
Shares Outstanding for Certain Class of Preferred Stock	0	0
Preferred Stock Class, 5 Percent Preferred [Member]
Class of Stock [Line Items]
Preferred Stock, Shares Authorized	127	127
Preferred Stock, Shares Issued	0	0
Preferred Stock, Shares Outstanding	0	0
Preferred Stock, Dividend Rate, Percentage	5.00%	5.00%
Minimum [Member] | Preferred Stock Class, Serial Preferred [Member]
Class of Stock [Line Items]
Preferred Stock, Dividend Rate, Percentage	6.00%	6.00%
Maximum [Member] | Preferred Stock Class, Serial Preferred [Member]
Class of Stock [Line Items]
Preferred Stock, Dividend Rate, Percentage	7.00%	7.00%

BHE Shareholders' Equity (Detai

BHE Shareholders' Equity (Details) - USD ($) $ in Millions	1 Months Ended	2 Months Ended	12 Months Ended
	Feb. 28, 2017	Feb. 28, 2015	Dec. 31, 2015
Class of Stock [Line Items]
Common stock, value, repurchased			$ 36
Common Stock [Member]
Class of Stock [Line Items]
Common stock repurchased (shares)		75,000
Common stock, value, repurchased		$ 36
Subsequent Event [Member] | Common Stock [Member]
Class of Stock [Line Items]
Common stock repurchased (shares)	35,000
Common stock, value, repurchased	$ 19

BHE Shareholders' Equity - Rest

BHE Shareholders' Equity - Restricted Net Assets (Details) $ in Billions	Dec. 31, 2016USD ($)
Stockholders' Equity Note [Abstract]
BHE restricted net assets	$ 15.1
BHE's subsidiaries restricted net assets	$ 17.6

Common Shareholder's Equity - P

Common Shareholder's Equity - PacifiCorp (Details) - PacifiCorp [Member] - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Feb. 28, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Class of Stock [Line Items]
Dividends, Common Stock, Cash		$ 875	$ 950	$ 725
Minimum Common Equity To Capitalization Percentage		44.00%
Percentage of preferred stock to be treated as common equity for common equity percentage calculation		50.00%
Actual common equity percentage as calculated in accordance with acquisition commitment		51.00%
Amount available for dividend distribution without prior approval		$ 1,900
Subsequent Event [Member]
Class of Stock [Line Items]
Dividends, Common Stock, Cash	$ 100

Components of Accumulated Ot269

Components of Accumulated Other Comprehensive Loss, Net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	$ (908)
Other comprehensive (loss) income, unrecognized amounts on retirement benefits	(9)	$ 52	$ 69
Other comprehensive (loss) income, foreign currency translation adjustment	(583)	(680)	(314)
Other comprehensive (loss) income, unrealized gains on cash flow hedges	19	(11)	(18)
Other comprehensive income (loss)	(603)	(414)	(397)
Ending balance	(1,511)	(908)
Accumulated Other Comprehensive Loss, Net [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance, unrecognized amounts on retirement benefits	(438)	(490)	(559)
Balance, foreign currency translation adjustment	(1,092)	(412)	(98)
Beginning balance	615	390	524
Beginning balance	7	18	36
Beginning balance	(908)	(494)	(97)
Other comprehensive (loss) income, unrecognized amounts on retirement benefits	(9)	52	69
Other comprehensive (loss) income, foreign currency translation adjustment	(583)	(680)	(314)
Other comprehensive (loss) income, unrealized gains on available-for-sale securities	(30)	225	(134)
Other comprehensive (loss) income, unrealized gains on cash flow hedges	19	(11)	(18)
Other comprehensive income (loss)	(603)	(414)	(397)
Balance, unrecognized amounts on retirement benefits	(447)	(438)	(490)
Balance, foreign currency translation adjustment	(1,675)	(1,092)	(412)
Ending balance	585	615	390
Ending balance	26	7	18
Ending balance	$ (1,511)	$ (908)	$ (494)

Components of Accumulated Ot270

Components of Accumulated Other Comprehensive Loss, Net - PacifiCorp (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
PacifiCorp [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	$ (12)	$ (11)

Components of Accumulated Ot271

Components of Accumulated Other Comprehensive Loss, Net - MEC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of accumulated other comprehensive income (loss)
Beginning balance	$ (908)
Unrealized (losses) gains on cash flow hedges, net of tax	19	$ (11)	$ (18)
Other comprehensive loss, net of tax	(603)	(414)	(397)
Ending balance	(1,511)	(908)
MidAmerican Energy Company [Member]
Schedule of accumulated other comprehensive income (loss)
Beginning balance	(30)
Unrealized gains (losses) on available-for-sale securities, net of tax	3	0	1
Unrealized (losses) gains on cash flow hedges, net of tax	0	(7)	(13)
Dividend, Noncash, Transfer Of Operations	90	0	0
Other comprehensive loss, net of tax	3	(7)	(12)
Ending balance	0	(30)
Accumulated Other Comprehensive Income (Loss) [Member]
Schedule of accumulated other comprehensive income (loss)
Beginning balance	615	390	524
Beginning balance	7	18	36
Beginning balance	(908)	(494)	(97)
Unrealized gains (losses) on available-for-sale securities, net of tax	(30)	225	(134)
Unrealized (losses) gains on cash flow hedges, net of tax	19	(11)	(18)
Other comprehensive loss, net of tax	(603)	(414)	(397)
Ending balance	585	615	390
Ending balance	26	7	18
Ending balance	(1,511)	(908)	(494)
Accumulated Other Comprehensive Income (Loss) [Member] | MidAmerican Energy Company [Member]
Schedule of accumulated other comprehensive income (loss)
Beginning balance	(3)	(3)
Beginning balance	(27)	(20)
Beginning balance	(30)	(23)
Unrealized gains (losses) on available-for-sale securities, net of tax	3	0
Unrealized (losses) gains on cash flow hedges, net of tax	0	(7)
Dividend, Noncash, Transfer Of Operations	27
Other comprehensive loss, net of tax	3	(7)	(12)
Ending balance	0	(3)	(3)
Ending balance	0	(27)	(20)
Ending balance	$ 0	$ (30)	$ (23)

Variable-Interest Entities - Pa

Variable-Interest Entities - PacifiCorp (Details) - PacifiCorp [Member] - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2014	Dec. 31, 2015
Variable Interest Entity (VIE) or Potential VIE, Information Unavailability [Member]
Schedule of Equity Method Investments [Line Items]
Variable Interest Entity, Measure of Activity, Purchases	$ 20,000,000	$ 38,000,000
Variable Interest Entity, Reporting Entity Involvement, Maximum Loss Exposure, Amount	$ 0
Variable Interest Entity, Not Primary Beneficiary [Member]
Schedule of Equity Method Investments [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage	66.67%
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets and Liabilities, Net	$ 165,000,000		$ 190,000,000
Hermiston [Member]
Schedule of Equity Method Investments [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Hermiston [Member] | Variable Interest Entity (VIE) or Potential VIE, Information Unavailability [Member]
Schedule of Equity Method Investments [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Percentage of natural gas for jointly owned utility plant procured by Company	100.00%
Percentage of electricity from jointly owned utility plant received by Company	100.00%
Percentage of electricity acquired from jointly owned utility plant by Company through long-term power purchase agreement	50.00%
Jointly Owned Utility Plant, Joint Owner Share	50.00%
Jim Bridger Unit Nos 1 thru 4 [Member]
Schedule of Equity Method Investments [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	67.00%
Jim Bridger Unit Nos 1 thru 4 [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Schedule of Equity Method Investments [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	66.67%
Jointly Owned Utility Plant, Joint Owner Share	33.33%
Share of coal production purchased by Company	66.67%
Share of coal production purchased by joint venture partner	33.33%

Noncontrolling Interests (Detai

Noncontrolling Interests (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Preferred Securities of Subsidiaries [Line Items]
Preferred stock of subsidiaries, value, outstanding noncontrolling interest, amount represented by preferred stock	$ 58	$ 58
PacifiCorp [Member]
Preferred Securities of Subsidiaries [Line Items]
Preferred stock of subsidiaries, value, outstanding noncontrolling interest, amount represented by preferred stock	2	2
Northern Electric Plc [Member]
Preferred Securities of Subsidiaries [Line Items]
Preferred stock of subsidiaries, value, outstanding noncontrolling interest, amount represented by preferred stock	$ 56	$ 56
Noncontrolling interest, dividend requirements of preferred stock	0.08061	0.08061

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Sales revenue from energy operations		$ 14,621	$ 15,354	$ 15,182
Real estate		2,801	2,526	2,144
Revenues		17,422	17,880	17,326
Depreciation and amortization - energy operations		2,560	2,399	2,028
Depreciation and amortization		2,591	2,428	2,057
Operating income (loss)		4,251	4,328	4,046
Interest expense		1,854	1,904	1,711
Capitalized interest		(139)	(74)	(89)
Allowance for equity funds		158	91	98
Investment Income, Interest and Dividend		120	107	38
Other, net		36	39	42
Income before income tax expense and equity income		2,850	2,735	2,602
Income tax expense		403	450	589
Payments to Acquire Property, Plant, and Equipment		5,090	5,875	6,555
Property, plant and equipment, net		62,509	60,769	59,248
Assets		85,440	83,618	81,816
PacifiCorp [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		5,201	5,232	5,252
Depreciation and amortization - energy operations		783	780	745
Operating income (loss)		1,427	1,344	1,308
Interest expense		381	383	386
Income tax expense		341	328	310
Payments to Acquire Property, Plant, and Equipment		903	916	1,066
Property, plant and equipment, net		19,162	19,039	18,755
Assets		23,563	23,550	23,404
MidAmerican Funding [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		2,631	2,515	2,844
Depreciation and amortization - energy operations		479	407	351
Operating income (loss)		566	451	395
Interest expense		218	206	197
Income tax expense		(139)	(150)	(122)
Payments to Acquire Property, Plant, and Equipment		1,637	1,448	1,527
Property, plant and equipment, net		12,835	11,737	10,535
Assets		17,571	16,315	15,164
NV Energy [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		2,895	3,351	3,241
Depreciation and amortization - energy operations		421	410	379
Operating income (loss)		770	812	791
Interest expense		250	262	283
Income tax expense		200	207	195
Payments to Acquire Property, Plant, and Equipment		529	571	558
Property, plant and equipment, net		9,825	9,767	9,648
Assets		14,320	14,656	14,256
Northern Powergrid Holdings [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		995	1,140	1,283
Depreciation and amortization - energy operations		200	202	198
Operating income (loss)		494	593	674
Interest expense		136	145	151
Income tax expense		22	35	110
Payments to Acquire Property, Plant, and Equipment		579	674	675
Property, plant and equipment, net		5,148	5,790	5,599
Assets		6,433	7,317	7,059
BHE Pipeline Group [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		978	1,016	1,078
Depreciation and amortization - energy operations		206	204	196
Operating income (loss)		455	464	439
Interest expense		50	66	76
Income tax expense		163	158	149
Payments to Acquire Property, Plant, and Equipment		226	240	257
Property, plant and equipment, net		4,423	4,345	4,286
Assets		5,144	4,953	4,951
BHE Transmission [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		502	592	62
Depreciation and amortization - energy operations		241	185	13
Operating income (loss)		92	260	16
Interest expense		153	146	14
Income tax expense		26	63	28
Payments to Acquire Property, Plant, and Equipment		466	966	222
Property, plant and equipment, net		5,810	5,301	5,567
Assets		8,378	7,553	7,979
BHE Renewables [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		743	728	623
Depreciation and amortization - energy operations		230	216	152
Operating income (loss)		256	255	314
Interest expense		198	193	175
Income tax expense		(32)	41	65
Payments to Acquire Property, Plant, and Equipment		719	1,034	2,221
Property, plant and equipment, net		5,302	4,805	4,897
Assets		7,010	5,892	6,082
HomeServices [Member]
Segment Reporting Information [Line Items]
Real estate		2,801	2,526	2,144
Depreciation and amortization		31	29	29
Operating income (loss)		212	184	125
Interest expense		2	3	4
Income tax expense		81	72	44
Payments to Acquire Property, Plant, and Equipment		20	16	17
Property, plant and equipment, net		78	70	68
Assets		1,776	1,705	1,622
Other [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations	[1]	676	780	799
Depreciation and amortization - energy operations	[1]	0	(5)	(6)
Operating income (loss)	[1]	(21)	(35)	(16)
Interest expense	[1]	466	500	425
Income tax expense	[1]	(259)	(304)	(190)
Payments to Acquire Property, Plant, and Equipment		11	10	12
Property, plant and equipment, net		(74)	(85)	(107)
Assets		1,245	1,677	1,299
UNITED STATES
Segment Reporting Information [Line Items]
Revenues		15,895	16,121	15,857
Income before income tax expense and equity income		2,264	2,034	2,001
Property, plant and equipment, net		51,671	49,680	47,918
United Kingdom
Segment Reporting Information [Line Items]
Revenues		995	1,140	1,281
Income before income tax expense and equity income		382	472	557
Property, plant and equipment, net		5,020	5,757	5,563
CANADA
Segment Reporting Information [Line Items]
Revenues		506	600	78
Income before income tax expense and equity income		135	165	4
Property, plant and equipment, net		5,803	5,298	5,570
The Philippines and other [Member]
Segment Reporting Information [Line Items]
Revenues		26	19	110
Income before income tax expense and equity income		69	64	40
Property, plant and equipment, net		$ 15	$ 34	$ 197
[1]	(1)The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other, relate to other corporate entities, including MidAmerican Energy Services, LLC, corporate functions and intersegment eliminations.

Segment Information - Goodwill

Segment Information - Goodwill (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Goodwill [Roll Forward]
Beginning balance	$ 9,076	$ 9,343
Acquisitions	50	77
Foreign currency translation	(86)	(318)
Other	(30)	(26)
Ending balance	9,010	9,076
PacifiCorp [Member]
Goodwill [Roll Forward]
Beginning balance	1,129	1,129
Acquisitions	0	0
Foreign currency translation	0	0
Other	0	0
Ending balance	1,129	1,129
MidAmerican Funding [Member]
Goodwill [Roll Forward]
Beginning balance	2,102	2,102
Acquisitions	0	0
Foreign currency translation	0	0
Other	0	0
Ending balance	2,102	2,102
NV Energy [Member]
Goodwill [Roll Forward]
Beginning balance	2,369	2,369
Acquisitions	0	0
Foreign currency translation	0	0
Other	0	0
Ending balance	2,369	2,369
Northern Powergrid Holdings [Member]
Goodwill [Roll Forward]
Beginning balance	1,056	1,100
Acquisitions	0	0
Foreign currency translation	(126)	(44)
Other	0	0
Ending balance	930	1,056
BHE Pipeline Group [Member]
Goodwill [Roll Forward]
Beginning balance	101	127
Acquisitions	0	0
Foreign currency translation	0	0
Other	(26)	(26)
Ending balance	75	101
BHE Transmission [Member]
Goodwill [Roll Forward]
Beginning balance	1,428	1,657
Acquisitions	4	44
Foreign currency translation	42	(273)
Other	(4)	0
Ending balance	1,470	1,428
BHE Renewables [Member]
Goodwill [Roll Forward]
Beginning balance	95	95
Acquisitions	0	0
Foreign currency translation	0	0
Other	0	0
Ending balance	95	95
HomeServices [Member]
Goodwill [Roll Forward]
Beginning balance	794	761
Acquisitions	46	33
Foreign currency translation	0	0
Other	0	0
Ending balance	840	794
Other [Member]
Goodwill [Roll Forward]
Beginning balance	2	3
Acquisitions	0	0
Foreign currency translation	(2)	(1)
Other	0	0
Ending balance	$ 0	$ 2

Segment Information - MEC (Deta

Segment Information - MEC (Details) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2016USD ($)OperatingSegmentsTheNumberOfReportableSegments	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | OperatingSegments									8
Revenues									$ 17,422	$ 17,880	$ 17,326
Operating income (loss)									4,251	4,328	4,046
Interest expense									1,854	1,904	1,711
Income tax (benefit) expense									403	450	589
Net income attributable to BHE shareholders									2,542	2,370	2,095
Payments to Acquire Property, Plant, and Equipment									5,090	5,875	6,555
Assets	$ 85,440				$ 83,618				$ 85,440	83,618	81,816
MidAmerican Energy Company [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | TheNumberOfReportableSegments									2
Electric Domestic Regulated Revenue									$ 1,985	1,837	1,817
Revenues	621	$ 795	$ 584	$ 625	528	$ 680	$ 572	$ 722	2,625	2,502	2,822
Utilities Operating Expense, Depreciation and Amortization									479	407	351
Operating income (loss)	42	284	139	100	29	208	112	100	565	449	394
Interest expense									196	183	174
Income tax (benefit) expense									(132)	(147)	(116)
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent					(3)	233	126	90	542	446	401
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent					6	1	5	4	0	16	16
Net income attributable to BHE shareholders	15	$ 320	$ 131	$ 76	3	$ 234	$ 131	$ 94	542	462	417
Payments to Acquire Property, Plant, and Equipment									1,636	1,446	1,526
Assets	15,459				14,385				15,459	14,385	13,234
MidAmerican Energy Company [Member] | Regulated Electric [Member]
Segment Reporting Information [Line Items]
Electric Domestic Regulated Revenue									1,985	1,837	1,817
Utilities Operating Expense, Depreciation and Amortization									436	366	312
Operating income (loss)									497	385	319
Interest expense									178	166	157
Income tax (benefit) expense									(156)	(163)	(138)
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent									512	413	361
Payments to Acquire Property, Plant, and Equipment									1,564	1,365	1,429
Assets	14,113				12,970				14,113	12,970	11,850
MidAmerican Energy Company [Member] | Regulated Gas [Member]
Segment Reporting Information [Line Items]
Gas Domestic Regulated Revenue									637	661	996
Utilities Operating Expense, Depreciation and Amortization									43	41	39
Operating income (loss)									68	64	75
Interest expense									18	17	17
Income tax (benefit) expense									22	16	22
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent									32	33	40
Payments to Acquire Property, Plant, and Equipment									72	81	97
Assets	1,345				1,251				1,345	1,251	1,217
MidAmerican Energy Company [Member] | Corporate and Other [Member]
Segment Reporting Information [Line Items]
Other Revenue, Net									3	4	9
Income tax (benefit) expense									2	0	0
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent									(2)	0	0
Assets	$ 1				$ 164				$ 1	$ 164	$ 167

Segment Information - MidAmeric

Segment Information - MidAmerican Funding (Details) $ in Millions	3 Months Ended								9 Months Ended	12 Months Ended
	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Dec. 31, 2016USD ($)OperatingSegmentsTheNumberOfReportableSegments	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | OperatingSegments										8
Revenues										$ 17,422	$ 17,880	$ 17,326
Operating income (loss)										4,251	4,328	4,046
Interest expense										1,854	1,904	1,711
Income tax (benefit) expense										403	450	589
Net income (loss) attributable to parent										2,542	2,370	2,095
Payments to Acquire Property, Plant, and Equipment										5,090	5,875	6,555
Assets	$ 85,440				$ 83,618					85,440	83,618	81,816
Goodwill	9,010				9,076					$ 9,010	9,076	9,343
MidAmerican Funding, LLC and Subsidiaries [Domain]
Segment Reporting Information [Line Items]
Number of Reportable Segments | TheNumberOfReportableSegments										2
Electric Domestic Regulated Revenue										$ 1,985	1,837	1,817
Revenues	623	$ 797	$ 585	$ 626	531		$ 576	$ 727	$ 681	2,631	2,515	2,844
Utilities Operating Expense, Depreciation and Amortization										479	407	351
Operating income (loss)	42	284	140	100	29		112	101	209	566	451	395
Interest expense										219	206	197
Income tax (benefit) expense										(139)	(150)	(122)
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent					(7)	$ 230	124	95		532	442	393
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent					6	$ 1	5	4		0	16	16
Net income (loss) attributable to parent	14	$ 318	$ 127	$ 73	(1)		$ 129	$ 99	$ 231	532	458	409
Payments to Acquire Property, Plant, and Equipment										1,636	1,446	1,526
Assets	16,747				15,674					16,747	15,674	14,522
Goodwill	1,270				1,270					1,270	1,270
MidAmerican Funding, LLC and Subsidiaries [Domain] | Regulated Electric [Member]
Segment Reporting Information [Line Items]
Electric Domestic Regulated Revenue										1,985	1,837	1,817
Utilities Operating Expense, Depreciation and Amortization										436	366	312
Operating income (loss)										497	385	319
Interest expense										178	166	157
Income tax (benefit) expense										(156)	(163)	(138)
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent										512	413	361
Payments to Acquire Property, Plant, and Equipment										1,564	1,365	1,429
Assets	15,304				14,161					15,304	14,161	13,041
Goodwill	1,191				1,191					1,191	1,191
MidAmerican Funding, LLC and Subsidiaries [Domain] | Regulated Gas [Member]
Segment Reporting Information [Line Items]
Gas Domestic Regulated Revenue										637	661	996
Utilities Operating Expense, Depreciation and Amortization										43	41	39
Operating income (loss)										68	64	75
Interest expense										18	17	17
Income tax (benefit) expense										22	16	22
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent										32	33	40
Payments to Acquire Property, Plant, and Equipment										72	81	97
Assets	1,424				1,330					1,424	1,330	1,296
Goodwill	79				79					79	79
MidAmerican Funding, LLC and Subsidiaries [Domain] | Corporate and Other [Member]
Segment Reporting Information [Line Items]
Other Revenue, Net										9	17	31
Operating income (loss)										1	2	1
Interest expense										23	23	23
Income tax (benefit) expense										(5)	(3)	(6)
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent										(12)	(4)	(8)
Assets	$ 19				$ 183					$ 19	$ 183	$ 185

Segment Information - SPPC (Det

Segment Information - SPPC (Details) $ in Millions		12 Months Ended
		Dec. 31, 2016USD ($)OperatingSegmentsTheNumberOfReportableSegments	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | OperatingSegments		8
Revenues		$ 17,422	$ 17,880	$ 17,326
Cost of sales		4,315	5,079	5,732
Operating income (loss)		4,251	4,328	4,046
Income tax expense		403	450	589
Payments to Acquire Property, Plant, and Equipment		5,090	5,875	6,555
Assets		$ 85,440	83,618	81,816
Sierra Pacific Power Company [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | TheNumberOfReportableSegments		2
Electric Domestic Regulated Revenue		$ 702	810	779
Gas Domestic Regulated Revenue		110	137	125
Revenues		812	947	904
Cost of sales		265	374	361
Cost of Purchased Oil and Gas		55	84	76
Cost of Sales		320	458	437
Gross Margin		492	489	467
Operations and maintenance		170	167	162
Utilities Operating Expense, Depreciation and Amortization		118	113	105
Operating income (loss)		180	184	178
Interest expense, net of borrowed funds		54	61	61
Income tax expense		49	47	47
Payments to Acquire Property, Plant, and Equipment		194	252	186
Assets		3,493	3,487	3,336
Sierra Pacific Power Company [Member] | Electric Operations [Member]
Segment Reporting Information [Line Items]
Electric Domestic Regulated Revenue		702	810	779
Cost of sales		265	374	361
Electric Domestic Regulated Gross Margin		437	436	418
Electricity, Utilities Operating Expense, Maintenance and Operations		153	149	143
Utilities Operating Expense, Depreciation and Amortization		101	96	90
Operating income (loss)		161	168	165
Electric, Interest Expense, net of allowance for borrowed funds		49	56	57
Income tax expense		44	43	43
Payments to Acquire Property, Plant, and Equipment		176	229	168
Assets		3,119	3,060	2,984
Sierra Pacific Power Company [Member] | Natural Gas Operations [Member]
Segment Reporting Information [Line Items]
Gas Domestic Regulated Revenue		110	137	125
Cost of Purchased Oil and Gas		55	84	76
Gas Domestic Regulated Gross Margin		55	53	49
Gas, Utilities Operating Expense, Maintenance and Operations		17	18	19
Utilities Operating Expense, Depreciation and Amortization		17	17	15
Operating income (loss)		19	16	13
Gas, Interest Expense, net of allowance for borrowed funds		5	5	4
Income tax expense		5	4	4
Payments to Acquire Property, Plant, and Equipment		18	23	18
Assets		314	316	322
Sierra Pacific Power Company [Member] | Regulated common assets [Member]
Segment Reporting Information [Line Items]
Assets	[1]	$ 60	$ 111	$ 30
[1]	Consists principally of cash and cash equivalents not included in either the regulated electric or regulated natural gas segments.

Subsequent Events (MEC) Subs279

Subsequent Events (MEC) Subsequent Events - MEC (Details) - USD ($) $ in Millions	Feb. 28, 2017	Dec. 31, 2016	Dec. 31, 2015
Subsequent Event [Line Items]
Par value		$ 36,295
MidAmerican Energy Company [Member]
Subsequent Event [Line Items]
Par value		4,332
MidAmerican Energy Company [Member] | MEC Notes, 5.95% Series, due 2017 [Member]
Subsequent Event [Line Items]
Par value		$ 250
Debt Instrument, Interest Rate, Stated Percentage		5.95%	5.95%
MidAmerican Energy Company [Member] | Subsequent Event [Member] | MidAmerican Energy Company [Member] | MEC First Mortgage Bonds, 3.10%, Due May 2027 [Member]
Subsequent Event [Line Items]
Par value	$ 375
Debt Instrument, Interest Rate, Stated Percentage	3.10%
MidAmerican Energy Company [Member] | Subsequent Event [Member] | MidAmerican Energy Company [Member] | MEC First Mortgage Bonds, 3.95%, Due 2047 [Member]
Subsequent Event [Line Items]
Par value	$ 475
Debt Instrument, Interest Rate, Stated Percentage	3.95%
MidAmerican Energy Company [Member] | Subsequent Event [Member] | MidAmerican Energy Company [Member] | MEC Notes, 5.95% Series, due 2017 [Member]
Subsequent Event [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.95%
Debt Instrument, Repurchased Face Amount	$ 250

Unaudited Quarterly Operatin280

Unaudited Quarterly Operating Results - MEC (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Quarterly Operating Results [Line Items]
Revenues									$ 17,422	$ 17,880	$ 17,326
Operating income (loss)									4,251	4,328	4,046
Net income attributable to BHE shareholders									2,542	2,370	2,095
MidAmerican Energy Company [Member]
Quarterly Operating Results [Line Items]
Revenues	$ 621	$ 795	$ 584	$ 625	$ 528	$ 680	$ 572	$ 722	2,625	2,502	2,822
Operating income (loss)	42	284	139	100	29	208	112	100	565	449	394
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent					(3)	233	126	90	542	446	401
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent					6	1	5	4	0	16	16
Net income attributable to BHE shareholders	$ 15	$ 320	$ 131	$ 76	$ 3	$ 234	$ 131	$ 94	$ 542	$ 462	$ 417

Unaudited Quarterly Operatin281

Unaudited Quarterly Operating Results - MidAmerican Funding (Details) - USD ($) $ in Millions	3 Months Ended								9 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Sep. 30, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Quarterly Operating Results [Line Items]
Revenues										$ 17,422	$ 17,880	$ 17,326
Operating income (loss)										4,251	4,328	4,046
Net income attributable to BHE shareholders										2,542	2,370	2,095
MidAmerican Funding, LLC and Subsidiaries [Domain]
Quarterly Operating Results [Line Items]
Revenues	$ 623	$ 797	$ 585	$ 626	$ 531		$ 576	$ 727	$ 681	2,631	2,515	2,844
Operating income (loss)	42	284	140	100	29		112	101	209	566	451	395
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent					(7)	$ 230	124	95		532	442	393
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent					6	$ 1	5	4		0	16	16
Net income attributable to BHE shareholders	$ 14	$ 318	$ 127	$ 73	$ (1)		$ 129	$ 99	$ 231	$ 532	$ 458	$ 409

Unaudited Quarterly Operatin282

Unaudited Quarterly Operating Results - NPC (Details) - USD ($) $ in Millions	3 Months Ended							9 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Jun. 30, 2015	Mar. 31, 2015	Sep. 30, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Quarterly Operating Results [Line Items]
Operating income (loss)									$ 4,251	$ 4,328	$ 4,046
Net income attributable to BHE shareholders									2,542	2,370	2,095
Nevada Power Company [Member]
Quarterly Operating Results [Line Items]
Electric Domestic Regulated Revenue	$ 393	$ 766	$ 525	$ 399	$ 458	$ 607	$ 459	$ 878
Operating income (loss)	69	324	141	46	74	136	74	329	580	613	541
Net income attributable to BHE shareholders	$ 22	$ 188	$ 66	$ 3	$ 17	$ 60	$ 24	$ 187	$ 279	$ 288	$ 227

Unaudited Quarterly Operatin283

Unaudited Quarterly Operating Results - SPPC (Details) - Sierra Pacific Power Company [Member] - USD ($) $ in Millions	3 Months Ended							9 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Jun. 30, 2015	Mar. 31, 2015	Sep. 30, 2015
Quarterly Operating Results [Line Items]
Electric Domestic Operating Revenue, Quarterly	$ 163	$ 207	$ 162	$ 170	$ 185	$ 201	$ 196	$ 228
Gas Domestic Operating Revenue, Quarterly	29	15	19	47	43	26	50	18
Operating Income (loss), Quarterly	42	69	28	41	38	37	43	66
Net Income (Loss) Attributable to Parent, Quarterly	$ 19	$ 38	$ 10	$ 17	$ 15	$ 16	$ 19	$ 33

Schedule I Condensed Balance284

Schedule I Condensed Balance Sheets (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents		$ 721	$ 1,108	$ 617	$ 1,175
Accounts receivable		1,751	1,785
Income tax receivable		0	319
Other current assets		917	814
Total current assets		4,673	5,243
Goodwill		9,010	9,076	9,343
Other assets		996	1,008
Total assets		85,440	83,618	81,816
Current liabilities:
Short-term debt	[1]	1,869	974
Total current liabilities		6,313	6,089
BHE senior debt		7,418	7,814
BHE junior subordinated debentures		944	2,944
Long-term Debt		36,116	37,972
Other long-term liabilities		2,742	2,854
Total liabilities		60,977	61,083
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		6,390	6,403
Retained earnings		19,448	16,906
Accumulated other comprehensive loss, net		(1,511)	(908)
Total shareholders' equity		24,327	22,401
Noncontrolling interest		136	134
Total equity		24,463	22,535	20,573	18,816
Total liabilities and equity		85,440	83,618
MidAmerican Funding LLC [Member]
Current assets:
Cash and cash equivalents		0	0	0	0
Due from Affiliates		2	2
Investments in subsidiaries		6,718	6,144
Total assets		6,720	6,146
Current liabilities:
Other accrued current liabilities		7	7
Long-term Debt		326	326
Notes payable - affiliate		301	288
Total liabilities		634	621
Shareholders' equity:
Paid-in capital		1,679	1,679
Retained earnings		4,407	3,876
Accumulated other comprehensive loss, net		0	(30)
Total shareholders' equity		6,086	5,525
Total liabilities and equity		6,720	6,146
Parent Company [Member]
Current assets:
Cash and cash equivalents		33	23	$ 3	$ 292
Accounts receivable		21	16
Due from Affiliates		105	0
Income tax receivable		0	167
Other current assets		2	2
Total current assets		161	208
Investments in subsidiaries		33,400	32,505
Other Investments		1,338	1,389
Goodwill		1,221	1,221
Other assets		1,171	1,340
Total assets		37,291	36,663
Current liabilities:
Accounts payable and other current liabilities		357	306
Notes Payable, Related Parties, Current		194	0
Short-term debt		834	253
Current portion of senior debt		400	0
Total current liabilities		1,785	559
BHE senior debt		7,418	7,814
BHE junior subordinated debentures		944	2,944
Notes payable - affiliate		1,859	1,985
Other long-term liabilities		942	946
Total liabilities		12,948	14,248
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		6,390	6,403
Retained earnings		19,448	16,906
Accumulated other comprehensive loss, net		(1,511)	(908)
Total shareholders' equity		24,327	22,401
Noncontrolling interest		16	14
Total equity		24,343	22,415
Total liabilities and equity		$ 37,291	$ 36,663
[1]	The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.

Schedule I Condensed Statements

Schedule I Condensed Statements of Operations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating costs and expenses:
Depreciation and amortization	$ 2,591	$ 2,428	$ 2,057
Total operating costs and expenses	13,171	13,552	13,280
Operating loss	4,251	4,328	4,046
Other income (expense):
Interest expense	(1,854)	(1,904)	(1,711)
Other, net	36	39	42
Total other income (expense)	(1,401)	(1,593)	(1,444)
Loss before income tax benefit and equity income	2,850	2,735	2,602
Income tax (benefit) expense	403	450	589
Equity income (loss)	123	115	109
Net income	2,570	2,400	2,122
Net income attributable to noncontrolling interests	28	30	27
Net income (loss) attributable to parent	2,542	2,370	2,095
MidAmerican Funding LLC [Member]
Other income (expense):
Interest Expense, Long-term Debt	22	22	22
Loss before income tax benefit and equity income	(22)	(22)	(22)
Income tax (benefit) expense	(9)	(8)	(9)
Equity income (loss)	545	472	422
Net income (loss) attributable to parent	532	458	409
Parent Company [Member]
Operating costs and expenses:
General and administration	51	58	51
Depreciation and amortization	4	3	3
Total operating costs and expenses	55	61	54
Operating loss	(55)	(61)	(54)
Other income (expense):
Interest expense	(527)	(556)	(476)
Other, net	37	14	4
Total other income (expense)	(490)	(542)	(472)
Loss before income tax benefit and equity income	(545)	(603)	(526)
Income tax (benefit) expense	(285)	(330)	(221)
Equity income (loss)	2,805	2,646	2,402
Net income	2,545	2,373	2,097
Net income attributable to noncontrolling interests	3	3	2
Net income (loss) attributable to parent	$ 2,542	$ 2,370	$ 2,095

Schedule I Condensed Stateme286

Schedule I Condensed Statements of Comprehensive Income Schedule I Condensed Statements of Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Net income attributable to BHE shareholders	$ 2,542	$ 2,370	$ 2,095
Net income	2,570	2,400	2,122
Other comprehensive loss, net of tax	(603)	(414)	(397)
Comprehensive income	1,967	1,986	1,725
Comprehensive income attributable to noncontrolling interests	28	30	27
Comprehensive income attributable to BHE shareholders	1,939	1,956	1,698
MidAmerican Funding LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Net income attributable to BHE shareholders	532	458	409
Other comprehensive loss, net of tax	3	(7)	(12)
Comprehensive income attributable to BHE shareholders	535	451	397
Parent Company [Member]
Condensed Financial Statements, Captions [Line Items]
Net income attributable to BHE shareholders	2,542	2,370	2,095
Net income	2,545	2,373	2,097
Other comprehensive loss, net of tax	(603)	(414)	(397)
Comprehensive income	1,942	1,959	1,700
Comprehensive income attributable to noncontrolling interests	3	3	2
Comprehensive income attributable to BHE shareholders	$ 1,939	$ 1,956	$ 1,698

Schedule I Condensed Stateme287

Schedule I Condensed Statements of Cash Flows Schedule I Condensed Statements of Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	$ 6,056	$ 6,980	$ 5,146
Cash flows from investing activities:
Purchases of available-for-sale securities	(141)	(144)	(150)
Proceeds from sale of investments	191	142	118
Other, net	(34)	41	(11)
Net cash flows from investing activities	(5,746)	(6,230)	(9,418)
Cash flows from financing activities:
Proceeds from BHE senior debt	0	0	1,478
Proceeds from BHE junior subordinated debentures	0	0	1,500
Payments for Repurchase of Common Stock	0	36	0
Net proceeds from (repayments of) short-term debt	879	(421)	1,055
Other, net	(65)	(73)	(44)
Net cash flows from financing activities	(690)	(255)	3,725
Net change in cash and cash equivalents	(387)	491	(558)
Cash and cash equivalents at beginning of period	1,108	617	1,175
Cash and cash equivalents at end of period	721	1,108	617
MidAmerican Funding LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	(13)	(13)	(13)
Cash flows from investing activities:
Net cash flows from investing activities	0	0	0
Cash flows from financing activities:
Net change in amounts payable to subsidiary	13	13	13
Net cash flows from financing activities	13	13	13
Net change in cash and cash equivalents	0	0	0
Cash and cash equivalents at beginning of period	0	0	0
Cash and cash equivalents at end of period	0	0	0
Parent Company [Member]
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	2,760	2,528	1,937
Cash flows from investing activities:
Investments in subsidiaries	(1,080)	(1,506)	(4,937)
Purchases of available-for-sale securities	(24)	(36)	(56)
Proceeds from sale of investments	20	47	35
Notes receivable from affiliate, net	(307)	19	(55)
Other, net	(5)	(7)	(7)
Net cash flows from investing activities	(1,396)	(1,483)	(5,020)
Cash flows from financing activities:
Proceeds from BHE senior debt	0	0	1,478
Proceeds from BHE junior subordinated debentures	0	0	1,500
Proceeds from issuance of BHE common stock	0	0	0
Repayments of BHE senior debt	0	0	(250)
Repayments of BHE subordinated debt	(2,000)	(850)	(300)
Payments for Repurchase of Common Stock	0	36	0
Net proceeds from (repayments of) short-term debt	581	(142)	395
Notes payable to affiliate, net	69	4	(30)
Other, net	(4)	(1)	1
Net cash flows from financing activities	(1,354)	(1,025)	2,794
Net change in cash and cash equivalents	10	20	(289)
Cash and cash equivalents at beginning of period	23	3	292
Cash and cash equivalents at end of period	$ 33	$ 23	$ 3

Condensed Financial Statemen288

Condensed Financial Statements - Other Investments (Details) - BYD Company Limited common stock [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Available-for-sale Securities, Equity Securities	$ 1,185	$ 1,238
Available-for-sale Securities, Change in Net Unrealized Holding Gain (Loss) before Taxes	953	1,006
Parent Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Available-for-sale Securities, Equity Securities	1,185	1,238
Available-for-sale Securities, Change in Net Unrealized Holding Gain (Loss) before Taxes	$ 953	$ 1,006

Condensed Financial Statemen289

Condensed Financial Statements - Dividends and Distributions (Details) - Parent Company [Member] - USD ($) $ in Millions	2 Months Ended	12 Months Ended
	Feb. 24, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Distribution [Line Items]
Proceeds from dividends received		$ 3,000	$ 3,000	$ 2,300
Subsequent Event [Member]
Distribution [Line Items]
Proceeds from dividends received	$ 160

Condensed Financial Statemen290

Condensed Financial Statements - Guarantees (Details) - Parent Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Debt Instrument [Line Items]
Guarantor obligations, related party disclosure	$ 336
Tax Equity Contributions	$ 288

Schedule I Condensed Financial

Schedule I Condensed Financial Statements Condensed Financial Statements - MidAmerican Funding - Payable to Affiliate (Details) - MidAmerican Funding LLC [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Net change in amounts payable to subsidiary	$ 13	$ 13	$ 13
MHC, Inc. [Member]
Condensed Financial Statements, Captions [Line Items]
Net change in amounts payable to subsidiary	$ 13	$ 13	$ 13

Schedule II Consolidated Val292

Schedule II Consolidated Valuation and Qualifying Accounts (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Allowance for Doubtful Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year		$ 31	$ 37	$ 33
Valuation Allowances and Reserves, Charged to Cost and Expense		39	33	37
Valuation Allowances and Reserves, Adjustments		0	0	0
Valuation Allowances and Reserves, Deductions		(37)	(39)	(33)
Balance at End of Year		33	31	37
Reserves not deducted from assets [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year	[1]	13	11	9
Valuation Allowances and Reserves, Charged to Cost and Expense	[1]	5	7	12
Valuation Allowances and Reserves, Adjustments	[1]	0	0	0
Valuation Allowances and Reserves, Deductions	[1]	(5)	(5)	(10)
Balance at End of Year	[1]	$ 13	$ 13	$ 11
[1]	serves not deducted from assets relate primarily to estimated liabilities for losses retained by BHE for workers compensation, public liability and property damage claims.

Schedule II Consolidated Val293

Schedule II Consolidated Valuation and Qualifying Accounts - MEC (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016
Allowance for Doubtful Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year		$ 31	$ 37	$ 33
Valuation Allowances and Reserves, Charged to Cost and Expense		39	33	37
Valuation Allowances and Reserves, Deductions		(37)	(39)	(33)
Valuation Allowances and Reserves, Balance		31	37	33	$ 33
Reserves not deducted from assets [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year	[1]	13	11	9
Valuation Allowances and Reserves, Charged to Cost and Expense	[1]	5	7	12
Valuation Allowances and Reserves, Deductions	[1]	(5)	(5)	(10)
Valuation Allowances and Reserves, Balance	[1]	13	11	9	13
MidAmerican Energy Company [Member] | Allowance for Doubtful Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year		6	7	10
Valuation Allowances and Reserves, Charged to Cost and Expense		7	7	7
Valuation Allowances and Reserves, Deductions		(6)	(8)	(10)
Valuation Allowances and Reserves, Balance		6	7	10	7
MidAmerican Energy Company [Member] | Reserves not deducted from assets [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year		13	11	9
Valuation Allowances and Reserves, Charged to Cost and Expense		5	7	12
Valuation Allowances and Reserves, Deductions		(5)	(5)	(10)
Valuation Allowances and Reserves, Balance		$ 13	$ 11	$ 9	$ 13
[1]	serves not deducted from assets relate primarily to estimated liabilities for losses retained by BHE for workers compensation, public liability and property damage claims.

Schedule II Consolidated Val294

Schedule II Consolidated Valuation and Qualifying Accounts Schedule II Consolidated Valuation and Qualifying Accounts - LLC - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Allowance for Doubtful Accounts [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Balance		$ 33	$ 31	$ 37	$ 33
Valuation Allowances and Reserves, Charged to Cost and Expense		39	33	37
Valuation Allowances and Reserves, Deductions		37	39	33
Reserves not deducted from assets [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Balance	[1]	13	13	11	9
Valuation Allowances and Reserves, Charged to Cost and Expense	[1]	5	7	12
Valuation Allowances and Reserves, Deductions	[1]	5	5	10
MidAmerican Funding, LLC and Subsidiaries [Domain] | Allowance for Doubtful Accounts [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Balance		7	6	7	10
Valuation Allowances and Reserves, Charged to Cost and Expense		7	7	7
Valuation Allowances and Reserves, Deductions		6	8	10
MidAmerican Funding, LLC and Subsidiaries [Domain] | Reserves not deducted from assets [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Balance		13	13	11	$ 9
Valuation Allowances and Reserves, Charged to Cost and Expense		5	7	12
Valuation Allowances and Reserves, Deductions		$ 5	$ 5	$ 10
[1]	serves not deducted from assets relate primarily to estimated liabilities for losses retained by BHE for workers compensation, public liability and property damage claims.

Discontinued Operations Disc295

Discontinued Operations Discontinued Operations (Details) - Unregulated Retail Services [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
MidAmerican Funding, LLC and Subsidiaries [Domain]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued operations, net assets and AOCI	$ 117
MidAmerican Energy Company [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued operations, revenue	905	$ 918
Discontinued operations, costs of sales	854	863
Discontinued operations, cash flows from operations	30	$ (22)
Discontinued operations, accounts receivable, Net	115
Discontinued operations, derivative assets	41
Discontinued operations, deferred tax assets	21
Discontinued operations, accounts payable	(49)
Discontinued operations, derivative liabilities	(42)
Discontinued operations, other assets and liabilities, net	4
Discontinued operations, accumulated other comprehensive income loss, net	27
Discontinued operations, net assets and AOCI	$ (117)