Nevada Power (NVP) 10-K 29 Feb 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2015	Jan. 31, 2016	Jun. 30, 2015
Document Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
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		77,391,144
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 [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	No
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, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents		$ 1,108	$ 617
Trade receivables, net		1,785	1,837
Income taxes receivable		319	1,156
Inventories
Fuel		353	320
Inventories		882	826
Mortgage loans held for sale		335	286
Regulatory assets		130	253
Other current assets		814	930
Total current assets		5,243	5,652
Property, plant and equipment, net		60,769	59,248
Goodwill		9,076	9,343
Regulatory assets		4,155	4,000
Investments and restricted cash and investments		3,367	2,803
Other assets		1,008	770
Total assets		83,618	81,816
Current liabilities:
Accounts payable		1,564	1,991
Accrued interest		469	454
Accrued property, income and other taxes		372	366
Accrued employee expenses		264	255
Regulatory liabilities		402	163
Short-term debt	[1]	974	1,445
Current portion of long-term debt		1,148	1,232
Other current liabilities		896	1,203
Total current liabilities		6,089	7,109
Regulatory liabilities		2,631	2,669
Asset Retirement Obligations, Noncurrent		829	687
BHE senior debt		7,814	7,810
BHE junior subordinated debentures		2,944	3,794
Subsidiary debt		26,066	25,616
Deferred income taxes		12,685	11,514
Other long-term liabilities		2,854	2,731
Total liabilities		$ 61,083	$ 61,243
Commitments and contingencies
Shareholders' equity:
Common stock		$ 0	$ 0
Additional paid-in capital		6,403	6,423
Retained earnings		16,906	14,513
Accumulated other comprehensive loss, net		(908)	(494)
Total shareholders' equity		22,401	20,442
Noncontrolling interests		134	131
Total equity		22,535	20,573
Total liabilities and equity		83,618	81,816
PacifiCorp [Member]
Current assets:
Cash and cash equivalents		12	23
Receivables, Net, Current		740	701
Income taxes receivable		17	133
Inventories
Materials and supplies		233	218
Fuel		192	199
Regulatory assets		102	131
Other current assets		81	92
Total current assets		1,377	1,497
Public Utilities, Property, Plant and Equipment, Net		19,026	18,719
Regulatory assets		1,583	1,574
Other assets		381	415
Total assets		22,367	22,205
Current liabilities:
Accounts payable		473	465
Accrued interest		115	110
Accrued property, income and other taxes		62	59
Accrued employee expenses		70	76
Regulatory liabilities		34	34
Short-term debt		20	20
Current portion of long-term debt and capital lease obligations		68	134
Other current liabilities		229	222
Total current liabilities		1,071	1,120
Regulatory liabilities		938	910
Asset Retirement Obligations, Noncurrent		189	114
Long-term debt and capital lease obligations		7,078	6,885
Deferred income taxes		4,750	4,581
Other long-term liabilities		1,027	953
Total liabilities		$ 14,864	$ 14,449
Commitments and contingencies
Shareholders' equity:
Preferred stock		$ 2	$ 2
Common stock		0	0
Additional paid-in capital		4,479	4,479
Retained earnings		3,033	3,288
Accumulated other comprehensive loss, net		(11)	(13)
Total shareholders' equity		7,503	7,756
Total liabilities and equity		22,367	22,205
MidAmerican Energy Company [Member]
Current assets:
Cash and cash equivalents		103	29
Receivables, Net, Current		342	433
Income taxes receivable		104	307
Inventories
Inventories		238	185
Other current assets		58	86
Total current assets		845	1,040
Public Utilities, Property, Plant and Equipment, Net		11,723	10,519
Regulatory assets		1,044	908
Investments and restricted cash and investments		634	625
Other assets		139	142
Total assets		14,385	13,234
Current liabilities:
Accounts payable		426	392
Accrued interest		46	40
Accrued property, income and other taxes		125	128
Short-term debt		0	50
Current portion of long-term debt and capital lease obligations		34	426
Other current liabilities		166	131
Total current liabilities		797	1,167
Regulatory liabilities		831	837
Asset Retirement Obligations, Noncurrent		488	432
Long-term debt and capital lease obligations		4,237	3,608
Deferred income taxes		3,061	2,662
Other long-term liabilities		266	278
Total liabilities		$ 9,680	$ 8,984
Commitments and contingencies
Shareholders' equity:
Common stock		$ 0	$ 0
Additional paid-in capital		561	561
Retained earnings		4,174	3,712
Accumulated other comprehensive loss, net		(30)	(23)
Total shareholders' equity		4,705	4,250
Total equity		4,705	4,250
Total liabilities and equity		14,385	13,234
MidAmerican Funding, LLC and Subsidiaries [Domain]
Current assets:
Cash and cash equivalents		103	30
Receivables, Net, Current		346	437
Income taxes receivable		104	303
Inventories
Inventories		238	185
Other current assets		58	86
Total current assets		849	1,041
Property, plant and equipment, net		11,737	10,535
Goodwill		1,270	1,270
Regulatory assets		1,044	908
Investments and restricted cash and investments		636	627
Other assets		138	141
Total assets		15,674	14,522
Current liabilities:
Accounts payable		427	392
Accrued interest		53	48
Accrued property, income and other taxes		125	128
Notes Payable, Related Parties, Current		139	136
Short-term debt		0	50
Current portion of long-term debt and capital lease obligations		34	426
Other current liabilities		166	131
Total current liabilities		944	1,311
Regulatory liabilities		831	837
Asset Retirement Obligations, Noncurrent		488	432
Long-term debt and capital lease obligations		4,563	3,934
Deferred income taxes		3,056	2,656
Other long-term liabilities		267	279
Total liabilities		$ 10,149	$ 9,449
Commitments and contingencies
Shareholders' equity:
Additional paid-in capital		$ 1,679	$ 1,679
Retained earnings		3,876	3,417
Accumulated other comprehensive loss, net		(30)	(23)
Total shareholders' equity		5,525	5,073
Total equity		5,525	5,073
Total liabilities and equity		15,674	14,522
Nevada Power Company [Member]
Current assets:
Cash and cash equivalents		536	220
Trade receivables, net		265	243
Inventories
Fuel		22	30
Inventories		80	88
Regulatory assets		0	57
Other current assets		46	32
Total current assets		927	640
Public Utilities, Property, Plant and Equipment, Net		6,996	7,003
Regulatory assets		1,057	1,069
Other assets		37	46
Total assets		9,017	8,758
Current liabilities:
Accounts payable		214	212
Accrued interest		54	60
Accrued property, income and other taxes		30	30
Regulatory liabilities		173	40
Long-term Debt and Capital and Financial Lease Obligations, Current		225	264
Customer Deposits, Current		58	55
Other current liabilities		28	36
Total current liabilities		782	697
Regulatory liabilities		304	326
Asset Retirement Obligations, Noncurrent		72	72
Long-term Debt and Capital and Financial Lease Obligations		3,060	3,280
Deferred income taxes		1,405	1,269
Other long-term liabilities		303	298
Total liabilities		5,854	5,870
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		2,308	2,308
Retained earnings		858	583
Accumulated other comprehensive loss, net		(3)	(3)
Total shareholders' equity		3,163	2,888
Total liabilities and equity		9,017	8,758
Sierra Pacific Power Company [Member]
Current assets:
Cash and cash equivalents		106	22
Trade receivables, net		124	127
Inventories
Fuel		5	8
Inventories		39	40
Regulatory assets		0	32
Other current assets		13	20
Total current assets		282	241
Public Utilities, Property, Plant and Equipment, Net		2,766	2,640
Regulatory assets		432	444
Other assets		7	11
Total assets		3,487	3,336
Current liabilities:
Accounts payable		127	127
Accrued interest		15	15
Accrued property, income and other taxes		13	12
Regulatory liabilities		78	39
Long-term Debt and Capital and Financial Lease Obligations, Current		453	1
Customer Deposits, Current		17	16
Other current liabilities		11	14
Total current liabilities		714	224
Regulatory liabilities		230	262
Asset Retirement Obligations, Noncurrent		10	8
Long-term Debt and Capital and Financial Lease Obligations		749	1,189
Deferred income taxes		570	524
Other long-term liabilities		148	139
Total liabilities		2,411	2,338
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		1,111	1,111
Retained earnings		(35)	(111)
Accumulated other comprehensive loss, net		0	(2)
Total shareholders' equity		1,076	998
Total liabilities and equity		$ 3,487	$ 3,336
[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, 2015	Dec. 31, 2014
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, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating revenue:
Energy	$ 15,354	$ 15,182	$ 10,826
Real estate	2,526	2,144	1,809
Total operating revenue	17,880	17,326	12,635
Energy:
Cost of sales	5,079	5,732	3,799
Operating expense	3,732	3,501	2,794
Depreciation and amortization	2,399	2,028	1,527
Real estate	2,342	2,019	1,680
Total operating costs and expenses	13,552	13,280	9,800
Operating income	4,328	4,046	2,835
Other income (expense):
Interest expense	(1,904)	(1,711)	(1,222)
Capitalized interest	74	89	84
Allowance for equity funds	91	98	78
Other Interest and Dividend Income	107	38	15
Other, net	39	42	51
Total other income (expense)	(1,593)	(1,444)	(994)
Income before income tax expense and equity income (loss)	2,735	2,602	1,841
Income tax expense	450	589	130
Equity income (loss)	115	109	(35)
Net income	2,400	2,122	1,676
Net income attributable to noncontrolling interests	30	27	40
Net income (loss) attributable to parent	2,370	2,095	1,636
PacifiCorp [Member]
Operating revenue:
Electric Domestic Regulated Revenue	5,232	5,252	5,147
Energy:
Energy costs	1,868	1,997	1,924
Operations and maintenance	1,082	1,057	1,114
Utilities Operating Expense, Depreciation and Amortization	757	726	675
Taxes, other than income taxes	185	172	170
Total operating costs and expenses	3,892	3,952	3,883
Operating income	1,340	1,300	1,264
Other income (expense):
Interest expense	(379)	(379)	(379)
Allowance for Funds Used During Construction, Capitalized Interest	18	25	29
Allowance for equity funds	33	51	57
Other, net	11	10	8
Total other income (expense)	(317)	(293)	(285)
Income before income tax expense and equity income (loss)	1,023	1,007	979
Income tax expense	328	309	297
Net income (loss) attributable to parent	695	698	682
MidAmerican Energy Company [Member]
Operating revenue:
Electric Domestic Regulated Revenue	1,837	1,817	1,762
Gas Domestic Regulated Revenue	661	996	824
Other Revenue, Net	909	927	817
Total operating revenue	3,407	3,740	3,403
Energy:
Energy costs	433	532	517
Cost of Natural Gas Purchases	397	720	558
Operations and maintenance	687	699	659
Utilities Operating Expense, Depreciation and Amortization	407	351	403
Taxes, other than income taxes	124	123	119
Cost of Sales Nonregulated	855	863	764
Other Cost and Expense, Operating	33	30	27
Total operating costs and expenses	2,936	3,318	3,047
Operating income	471	422	356
Other income (expense):
Interest expense	(183)	(174)	(151)
Allowance for Funds Used During Construction, Capitalized Interest	8	16	7
Allowance for equity funds	20	39	19
Other, net	5	10	16
Total other income (expense)	(150)	(109)	(109)
Income before income tax expense and equity income (loss)	321	313	247
Income tax expense	(141)	(104)	(103)
Net income	462	417	350
Preferred Stock Dividends and Other Adjustments	0	0	1
Net Income (Loss) Available to Common Stockholders, Basic	462	417	349
MidAmerican Funding, LLC and Subsidiaries [Domain]
Operating revenue:
Electric Domestic Regulated Revenue	1,837	1,817	1,762
Gas Domestic Regulated Revenue	661	996	824
Other Revenue, Net	922	949	827
Total operating revenue	3,420	3,762	3,413
Energy:
Energy costs	433	532	517
Cost of Natural Gas Purchases	397	720	558
Operations and maintenance	687	699	659
Utilities Operating Expense, Depreciation and Amortization	407	351	403
Taxes, other than income taxes	124	123	119
Cost of Sales Nonregulated	864	881	764
Other Cost and Expense, Operating	35	33	36
Total operating costs and expenses	2,947	3,339	3,056
Operating income	473	423	357
Other income (expense):
Interest expense	(206)	(197)	(174)
Allowance for Funds Used During Construction, Capitalized Interest	8	16	7
Allowance for equity funds	20	39	19
Other, net	19	18	22
Total other income (expense)	(159)	(124)	(126)
Income before income tax expense and equity income (loss)	314	299	231
Income tax expense	(144)	(110)	(110)
Net income	458	409	341
Net income attributable to noncontrolling interests	0	0	1
Net income (loss) attributable to parent	458	409	340
Nevada Power Company [Member]
Operating revenue:
Electric Domestic Regulated Revenue	2,402	2,337	2,092
Energy:
Cost of sales	1,084	1,076	835
Operations and maintenance	365	405	455
Utilities Operating Expense, Depreciation and Amortization	297	274	277
Taxes, other than income taxes	43	41	38
Business Combination, Acquisition Related Costs	0	0	52
Total operating costs and expenses	1,789	1,796	1,657
Operating income	613	541	435
Other income (expense):
Interest expense	(190)	(208)	(215)
Allowance for Funds Used During Construction, Capitalized Interest	3	1	6
Allowance for equity funds	4	1	8
Other, net	20	22	5
Total other income (expense)	(163)	(184)	(196)
Income before income tax expense and equity income (loss)	450	357	239
Income tax expense	162	130	94
Net income (loss) attributable to parent	288	227	145
Sierra Pacific Power Company [Member]
Operating revenue:
Electric Domestic Regulated Revenue	810	779	747
Gas Domestic Regulated Revenue	137	125	106
Total operating revenue	947	904	853
Energy:
Cost of sales	374	361	292
Cost of Purchased Oil and Gas	84	76	56
Operations and maintenance	163	158	197
Utilities Operating Expense, Depreciation and Amortization	113	105	123
Taxes, other than income taxes	29	26	25
Business Combination, Acquisition Related Costs	0	0	20
Total operating costs and expenses	763	726	713
Operating income	184	178	140
Other income (expense):
Interest expense	(61)	(61)	(61)
Allowance for Funds Used During Construction, Capitalized Interest	2	2	1
Allowance for equity funds	2	3	2
Other, net	3	12	6
Total other income (expense)	(54)	(44)	(52)
Income before income tax expense and equity income (loss)	130	134	88
Income tax expense	47	47	33
Net income (loss) attributable to parent	$ 83	$ 87	$ 55

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net income	$ 2,400	$ 2,122	$ 1,676
Net income (loss) attributable to parent	2,370	2,095	1,636
Other comprehensive (loss) income, net of tax:
Unrecognized amounts on retirement benefits, net of tax	52	69	16
Foreign currency translation adjustment	(680)	(314)	74
Unrealized gains (losses) on available-for-sale securities, net of tax	225	(134)	263
Unrealized (losses) gains on cash flow hedges, net of tax	(11)	(18)	13
Total other comprehensive (loss) income, net of tax	(414)	(397)	366
Comprehensive income	1,986	1,725	2,042
Comprehensive income attributable to noncontrolling interests	30	27	40
Comprehensive income attributable to shareholders	1,956	1,698	2,002
Parent Company [Member]
Net income	2,373	2,097	1,637
Net income (loss) attributable to parent	2,370	2,095	1,636
Other comprehensive (loss) income, net of tax:
Total other comprehensive (loss) income, net of tax	(414)	(397)	366
Comprehensive income	1,959	1,700	2,003
Comprehensive income attributable to noncontrolling interests	3	2	1
Comprehensive income attributable to shareholders	1,956	1,698	2,002
PacifiCorp [Member]
Net income (loss) attributable to parent	695	698	682
Other comprehensive (loss) income, net of tax:
Unrecognized amounts on retirement benefits, net of tax	2	(4)	3
Total other comprehensive (loss) income, net of tax	2	(4)	3
Comprehensive income attributable to shareholders	697	694	685
MidAmerican Energy Company [Member]
Net income	462	417	350
Other comprehensive (loss) income, net of tax:
Unrealized gains (losses) on available-for-sale securities, net of tax	0	1	1
Unrealized (losses) gains on cash flow hedges, net of tax	(7)	(13)	12
Total other comprehensive (loss) income, net of tax	(7)	(12)	13
Comprehensive income	455	405	363
MidAmerican Funding, LLC and Subsidiaries [Domain]
Net income	458	409	341
Net income (loss) attributable to parent	458	409	340
Other comprehensive (loss) income, net of tax:
Unrealized gains (losses) on available-for-sale securities, net of tax	0	1	1
Unrealized (losses) gains on cash flow hedges, net of tax	(7)	(13)	12
Total other comprehensive (loss) income, net of tax	(7)	(12)	13
Comprehensive income	451	397	354
Comprehensive income attributable to noncontrolling interests	0	0	1
Comprehensive income attributable to shareholders	$ 451	$ 397	$ 353

Consolidated Statements of Com6

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income tax effect - unrecognized amounts on retirement benefits	$ 17	$ 19	$ 7
Income tax effect - unrealized gains (losses) on available-for-sale securities	129	(84)	178
Income tax effect - unrealized (losses) gains on cash flow hedges	(7)	(13)	10
MidAmerican Funding, LLC and Subsidiaries [Domain]
Income tax effect - unrealized gains (losses) on available-for-sale securities	0	1	1
Income tax effect - unrealized (losses) gains on cash flow hedges	(4)	(10)	9
MidAmerican Energy Company [Member]
Income tax effect - unrealized gains (losses) on available-for-sale securities	0	1	1
Income tax effect - unrealized (losses) gains on cash flow hedges	(4)	(10)	9
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]Preferred Stock [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]	MidAmerican Funding, LLC and Subsidiaries [Domain]Noncontrolling Interest [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]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance							$ 7,644	$ 41	$ 0	$ 4,479	$ 3,136	$ (12)											$ 1,039	$ 0	$ 1,111	$ (71)	$ (1)	$ 2,922	$ 0	$ 2,308	$ 619	$ (5)
Balance (shares) at Dec. 31, 2012		75,000,000																						1,000					1,000
Balance at Dec. 31, 2012	$ 15,910	$ 0	$ 5,423	$ 10,782	$ (463)	$ 168							$ 3,635	$ 27	$ 562	$ 3,070	$ (24)	$ 4,351	$ 1,679	$ 2,669	$ (24)	$ 27
Balance at Dec. 31, 2013							7,787	2	0	4,479	3,315	(9)											1,016	$ 0	1,111	(93)	(2)	2,890	$ 0	2,308	586	(4)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,660	0	0	1,636	0	24
Net income	1,676												350			350		341		340		1
Net income attributable to BHE shareholders	1,636						682		0	0	682	0						340					55			55		145			145
Other comprehensive income (loss)	366	0	0	0	366	0	3		0	0	0	3	13				13	13			13
Distributions	(22)	0	0	0	0	(22)												(28)
Preferred stock dividends declared							(2)		0	0	(2)	0
Common stock dividends declared							(500)		0	0	(500)	0	(125)			(125)							(77)			(77)		(178)			(178)
Redemption of preferred securities of subsidiaries	(68)	$ 0	0	0	0	(68)																(28)
Stock Redeemed or Called During Period, Value							(40)	(39)	0	0	(1)	0	(28)
Common stock issuances (shares)		2,000,000
Common stock issuances	1,000	$ 0	1,000	0	0	0
Other equity transactions	(30)	$ 0	(33)	0	0	3																	(1)				(1)	1				1
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							3,845	0	561	3,295	(11)	4,677	1,679	3,009	(11)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance							7,787	2	0	4,479	3,315	(9)											1,016	$ 0	1,111	(93)	(2)	2,890	$ 0	2,308	586	(4)
Balance							7,787	2	0	4,479	3,315	(9)											1,016	0	1,111	(93)	(2)	2,890	0	2,308	586	(4)
Balance at Dec. 31, 2014	20,442						7,756	2	0	4,479	3,288	(13)	4,250					5,073					998	$ 0	1,111	(111)	(2)	2,888	$ 0	2,308	583	(3)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,112	0	0	2,095	0	17
Net income	2,122												417			417		409		409		0
Net income attributable to BHE shareholders	2,095						698		0	0	698	0						409					87			87		227			227
Other comprehensive income (loss)	(397)	0	0	0	(397)	0	(4)		0	0	0	(4)	(12)				(12)	(12)			(12)
Distributions	(22)	0	0	0	0	(22)
Common stock dividends declared							$ (725)		0	0	(725)	0											$ (105)			(105)		(230)			(230)
Stock Redeemed or Called During Period, Value													(28)	(27)	$ (1)
Other equity transactions	$ 64	$ 0	33	0	0	31												1		1								$ 1				1
Balance (shares) at Dec. 31, 2014	77,000,000	77,000,000					357,000,000								70,980,203								1,000	1,000				1,000	1,000
Balance at Dec. 31, 2014	$ 20,573	$ 0	6,423	14,513	(494)	131							4,250	0	$ 561	3,712	(23)	5,073	1,679	3,417	(23)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance	20,442						$ 7,756	2	0	4,479	3,288	(13)	4,250					5,073					$ 998	$ 0	1,111	(111)	(2)	$ 2,888	$ 0	2,308	583	(3)
Balance	20,442						7,756	2	0	4,479	3,288	(13)	4,250					5,073					998	0	1,111	(111)	(2)	2,888	0	2,308	583	(3)
Balance at Dec. 31, 2015	22,401						7,503	2	0	4,479	3,033	(11)	4,705					5,525					1,076	$ 0	1,111	(35)	0	3,163	$ 0	2,308	858	(3)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,388	0	0	2,370	0	18
Net income	2,400												462			462		458		458		0
Net income attributable to BHE shareholders	2,370						695		0	0	695	0						458					83			83		288			288
Other comprehensive income (loss)	(414)	0	0	0	(414)	0	2		0	0	0	2	(7)				(7)	(7)			(7)
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	0	0	56	0	11
Common stock, value, repurchased	(36)	0	(3)	(33)	0	0
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							4,705	$ 0	$ 561	$ 4,174	$ (30)	5,525	$ 1,679	$ 3,876	$ (30)	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance	22,401						$ 7,503	2	0	4,479	3,033	(11)	4,705					5,525					$ 1,076	$ 0	1,111	(35)	0	$ 3,163	$ 0	2,308	858	(3)
Balance	$ 22,401						$ 7,503	$ 2	$ 0	$ 4,479	$ 3,033	$ (11)	$ 4,705					$ 5,525					$ 1,076	$ 0	$ 1,111	$ (35)	$ 0	$ 3,163	$ 0	$ 2,308	$ 858	$ (3)

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash flows from operating activities:
Net income	$ 2,400	$ 2,122	$ 1,676
Net income attributable to BHE shareholders	2,370	2,095	1,636
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	2,428	2,057	1,560
Allowance for equity funds	(91)	(98)	(78)
Equity (income) loss, net of distributions	(115)	(109)	35
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions	(38)	(79)	52
Changes in regulatory assets and liabilities	356	(168)	(6)
Deferred income taxes and amortization of investment tax credits	1,265	2,335	996
Other, net	11	147	20
Changes in other operating assets and liabilities, net of effects from acquisitions:
Trade receivables and other assets	(9)	(44)	75
Derivative collateral, net	(14)	(70)	48
Pension and other postretirement benefit plans	(11)	86	(42)
Accrued property, income and other taxes	877	(1,117)	189
Accounts payable and other liabilities	(194)	(25)	179
Net cash flows from operating activities	6,980	5,146	4,669
Cash flows from investing activities:
Capital expenditures	(5,875)	(6,555)	(4,307)
Acquisitions, net of cash acquired	(164)	(2,956)	(5,536)
(Increase) decrease in restricted cash and investments	(28)	173	(234)
Purchases of available-for-sale securities	(144)	(150)	(228)
Proceeds from sales of available-for-sale securities	142	118	191
Equity method investments	(202)	(37)	(93)
Other, net	41	(11)	13
Net cash flows from investing activities	(6,230)	(9,418)	(10,194)
Cash flows from financing activities:
Proceeds from BHE senior debt	0	1,478	1,981
Proceeds from BHE junior subordinated debentures	0	1,500	2,594
Proceeds from issuance of BHE common stock	0	0	1,000
Repayments of BHE senior debt and junior subordinated debentures	(850)	(550)	0
Payments for Repurchase of Common Stock	(36)	0	0
Proceeds from subsidiary debt	2,479	1,257	2,460
Repayments of subsidiary debt	(1,354)	(971)	(1,156)
Net (repayments of) proceeds from short-term debt	(421)	1,055	(849)
Other, net	(73)	(44)	(104)
Net cash flows from financing activities	(255)	3,725	5,926
Effect of exchange rate changes	(4)	(11)	(2)
Net change in cash and cash equivalents	491	(558)	399
Cash and cash equivalents at beginning of period	617	1,175	776
Cash and cash equivalents at end of period	1,108	617	1,175
Parent Company [Member]
Cash flows from operating activities:
Net income	2,373	2,097	1,637
Net income attributable to BHE shareholders	2,370	2,095	1,636
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	3	3	1
Equity (income) loss, net of distributions	(2,646)	(2,402)	(1,679)
Changes in other operating assets and liabilities, net of effects from acquisitions:
Net cash flows from operating activities	2,528	1,937	2,295
Cash flows from investing activities:
Investments in subsidiaries	1,506	4,937	6,522
Purchases of available-for-sale securities	(36)	(56)	(106)
Proceeds from sales of available-for-sale securities	47	35	89
Repayment of (Issuance of) Notes Receivable with Related Parties, Net	19	(55)	(37)
Other, net	(7)	(7)	(16)
Net cash flows from investing activities	(1,483)	(5,020)	(6,592)
Cash flows from financing activities:
Proceeds from BHE senior debt	0	1,478	1,981
Proceeds from BHE junior subordinated debentures	0	1,500	2,594
Proceeds from issuance of BHE common stock	0	0	1,000
Payments for Repurchase of Common Stock	(36)	0	0
Net (repayments of) proceeds from short-term debt	(142)	395	(825)
Notes payable to affiliate, net	4	(30)	(173)
Other, net	(1)	1	(1)
Net cash flows from financing activities	(1,025)	2,794	4,576
Net change in cash and cash equivalents	20	(289)	279
Cash and cash equivalents at beginning of period	3	292	13
Cash and cash equivalents at end of period	23	3	292
Repayments of BHE senior debt	0	250	0
Repayments of BHE subordinated debt	850	300	0
PacifiCorp [Member]
Cash flows from operating activities:
Net income attributable to BHE shareholders	695	698	682
Adjustments to reconcile net income to net cash flows from operating activities:
Utilities Operating Expense, Depreciation and Amortization	757	726	675
Allowance for equity funds	(33)	(51)	(57)
Changes in regulatory assets and liabilities	63	(112)	(32)
Deferred income taxes and amortization of investment tax credits	172	297	230
Other, net	6	22	21
Changes in other operating assets and liabilities, net of effects from acquisitions:
Trade receivables and other assets	5	5	(7)
Derivative collateral, net	(47)	(16)	43
Increase (Decrease) in Inventories	(7)	37	14
Increase (Decrease) in Income Taxes Payable, Net of Income Taxes Receivable	116	(155)	(26)
Accounts payable and other liabilities	7	119	10
Net cash flows from operating activities	1,734	1,570	1,553
Cash flows from investing activities:
Capital expenditures	(916)	(1,066)	(1,065)
Other, net	(2)	(13)	16
Net cash flows from investing activities	(918)	(1,079)	(1,049)
Cash flows from financing activities:
Proceeds from Issuance of Long-term Debt	248	422	297
Net (repayments of) proceeds from short-term debt	0	20	0
Repayments of long-term debt and capital lease obligations (PacifiCorp)	(124)	(238)	(284)
Redemption of preferred stock	0	0	(40)
Common stock dividends	(950)	(725)	(500)
Preferred stock dividends	0	0	(2)
Other, net	(1)	0	(2)
Net cash flows from financing activities	(827)	(521)	(531)
Net change in cash and cash equivalents	(11)	(30)	(27)
Cash and cash equivalents at beginning of period	23	53	80
Cash and cash equivalents at end of period	12	23	53
MidAmerican Energy Company [Member]
Cash flows from operating activities:
Net income	462	417	350
Adjustments to reconcile net income to net cash flows from operating activities:
Utilities Operating Expense, Depreciation and Amortization	407	351	403
Deferred income taxes and amortization of investment tax credits	275	300	103
Increase (Decrease) in Other Current Assets and Liabilities, Net	12	1	22
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net	49	47	57
Other, net	(58)	(57)	(27)
Changes in other operating assets and liabilities, net of effects from acquisitions:
Increase (Decrease) in Accounts and Other Receivables	(91)	3	58
Derivative collateral, net	33	(53)	5
Increase (Decrease) in Inventories	(53)	44	13
Pension and other postretirement benefit plans	(8)	(2)	8
Accrued property, income and other taxes	217	(252)	(164)
Increase (Decrease) in Accounts Payable	(76)	30	23
Increase (Decrease) in Other Current Assets and Liabilities, Net	(12)	(1)	(22)
Net cash flows from operating activities	1,351	823	735
Cash flows from investing activities:
Capital expenditures	(1,446)	(1,526)	(1,026)
Purchases of available-for-sale securities	(142)	(88)	(114)
Proceeds from sales of available-for-sale securities	135	80	102
Proceeds from Sales of Business, Affiliate and Productive Assets	0	8	15
Other, net	3	5	11
Net cash flows from investing activities	(1,450)	(1,521)	(1,012)
Cash flows from financing activities:
Proceeds from subsidiary debt	649	840	940
Net (repayments of) proceeds from short-term debt	(50)	50	0
Repayments of Long-term Debt	426	356	670
Redemption of preferred stock	0	0	(28)
Common stock dividends	0	0	(125)
Other, net	0	(1)	0
Net cash flows from financing activities	173	533	117
Net change in cash and cash equivalents	74	(165)	(160)
Cash and cash equivalents at beginning of period	29	194	354
Cash and cash equivalents at end of period	103	29	194
MidAmerican Funding, LLC and Subsidiaries [Domain]
Cash flows from operating activities:
Net income	458	409	341
Net income attributable to BHE shareholders	458	409	340
Adjustments to reconcile net income to net cash flows from operating activities:
Utilities Operating Expense, Depreciation and Amortization	407	351	403
Deferred income taxes and amortization of investment tax credits	276	298	102
Increase (Decrease) in Other Current Assets and Liabilities, Net	12	0	22
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net	49	47	57
Other, net	(69)	(49)	(29)
Changes in other operating assets and liabilities, net of effects from acquisitions:
Increase (Decrease) in Accounts and Other Receivables	(93)	2	60
Derivative collateral, net	33	(53)	5
Increase (Decrease) in Inventories	(53)	44	13
Pension and other postretirement benefit plans	(8)	(2)	8
Accrued property, income and other taxes	213	(253)	(164)
Increase (Decrease) in Accounts Payable	(76)	30	23
Increase (Decrease) in Other Current Assets and Liabilities, Net	(12)	0	(22)
Net cash flows from operating activities	1,335	820	721
Cash flows from investing activities:
Capital expenditures	(1,446)	(1,526)	(1,026)
Purchases of available-for-sale securities	(142)	(88)	(114)
Proceeds from sales of available-for-sale securities	135	80	102
Proceeds from Sales of Business, Affiliate and Productive Assets	13	10	16
Other, net	2	5	10
Net cash flows from investing activities	(1,438)	(1,519)	(1,012)
Cash flows from financing activities:
Proceeds from subsidiary debt	649	840	940
Net (repayments of) proceeds from short-term debt	(50)	50	0
Repayments of Long-term Debt	426	356	670
Increase (Decrease) in Notes Payable, Related Parties, Current	3	1	(111)
Payments for Repurchase of Redeemable Noncontrolling Interest	0	0	28
Net cash flows from financing activities	176	535	131
Net change in cash and cash equivalents	73	(164)	(160)
Cash and cash equivalents at beginning of period	30	194	354
Cash and cash equivalents at end of period	103	30	194
Nevada Power Company [Member]
Cash flows from operating activities:
Net income attributable to BHE shareholders	288	227	145
Adjustments to reconcile net income to net cash flows from operating activities:
Other Nonrecurring (Income) Expense	(3)	15	0
Utilities Operating Expense, Depreciation and Amortization	297	274	277
Allowance for equity funds	(4)	(1)	(8)
Changes in regulatory assets and liabilities	4	2	103
Deferred Energy Change	176	(44)	(105)
Amortization of Deferred Charges	(36)	(79)	54
Deferred income taxes and amortization of investment tax credits	162	130	95
Other, net	13	68	69
Changes in other operating assets and liabilities, net of effects from acquisitions:
Trade receivables and other assets	(40)	(19)	(5)
Increase (Decrease) in Inventories	9	(15)	10
Accounts payable and other liabilities	(46)	(12)	21
Net cash flows from operating activities	892	704	548
Cash flows from investing activities:
Capital expenditures	(320)	(371)	(233)
Proceeds from Sale of Other Property, Plant, and Equipment	9	0	14
Other, net	10	0	3
Net cash flows from investing activities	(301)	(371)	(216)
Cash flows from financing activities:
Repayments of Long-term Debt	262	9	229
Common stock dividends	(13)	(230)	(178)
Net cash flows from financing activities	(275)	(239)	(407)
Net change in cash and cash equivalents	316	94	(75)
Cash and cash equivalents at beginning of period	220	126	201
Cash and cash equivalents at end of period	536	220	126
Sierra Pacific Power Company [Member]
Cash flows from operating activities:
Net income attributable to BHE shareholders	83	87	55
Adjustments to reconcile net income to net cash flows from operating activities:
Other Nonrecurring (Income) Expense	0	14	0
Utilities Operating Expense, Depreciation and Amortization	113	105	123
Allowance for equity funds	(2)	(3)	(2)
Changes in regulatory assets and liabilities	21	23	(74)
Deferred Energy Change	(81)	30	24
Amortization of Deferred Charges	(17)	(19)	(43)
Deferred income taxes and amortization of investment tax credits	47	47	36
Other, net	(9)	20	14
Changes in other operating assets and liabilities, net of effects from acquisitions:
Trade receivables and other assets	15	28	(8)
Increase (Decrease) in Inventories	1	3	17
Accounts payable and other liabilities	17	(21)	(16)
Net cash flows from operating activities	342	246	226
Cash flows from investing activities:
Capital expenditures	(252)	(186)	(139)
Other, net	2	0	0
Net cash flows from investing activities	(250)	(186)	(139)
Cash flows from financing activities:
Proceeds from Issuance of Long-term Debt	0	0	247
Repayments of Long-term Debt	1	1	251
Common stock dividends	(7)	(105)	(77)
Other, net	0	(1)	0
Net cash flows from financing activities	(8)	(105)	(81)
Net change in cash and cash equivalents	84	(45)	6
Cash and cash equivalents at beginning of period	22	67	61
Cash and cash equivalents at end of period	$ 106	$ 22	$ 67

Schedule I Condensed Balance Sh

Schedule I Condensed Balance Sheets (Paranthetical) - $ / shares shares in Millions	Dec. 31, 2015	Dec. 31, 2014
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, 2015
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 the states 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	Company Organization 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	Company Organization 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, 2015
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, 2015 and 2014 , the allowance for doubtful accounts totaled $31 million and $37 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 $353 million and $320 million as of December 31, 2015 and 2014 , respectively, and materials and supplies totaling $529 million and $506 million as of December 31, 2015 and 2014 , 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 $8 million and $41 million higher as of December 31, 2015 and 2014 , 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 2015 and 2014 , the Company did not record any goodwill impairments. The Company recognized a goodwill impairment of $53 million during 2013. 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, 2015 and 2014 , unbilled revenue was $660 million and $666 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, 2015 and 2014 , these amounts were recognized as regulatory assets of $1.5 billion and $1.4 billion , respectively, and regulatory liabilities of $29 million and $24 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, 2015 . 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 January 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-01, which amends FASB Accounting Standards Codification ("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. In November 2015, the FASB issued ASU No. 2015-17, which amends FASB ASC Topic 740, "Income Taxes." The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. The Company early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in other current assets of $291 million , other current liabilities of $3 million and noncurrent deferred income tax liabilities of $288 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. The Company early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets of $197 million , BHE senior debt of $50 million and subsidiary debt of $147 million as of December 31, 2014. 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. 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. 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 milli
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, 2015 and 2014 , 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): 2015 2014 2013 Beginning balance $ 7 $ 8 $ 9 Charged to operating costs and expenses, net 10 11 13 Write-offs, net (10 ) (12 ) (14 ) Ending balance $ 7 $ 7 $ 8 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 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. Revenue Recognition Revenue is recognized as electricity is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31, 2015 and 2014 , unbilled revenue was $245 million and $243 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 $437 million and $446 million as of December 31, 2015 and 2014 , respectively, and regulatory liabilities of $12 million and $13 million as of December 31, 2015 and 2014 , 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 $23 million and $27 million as of December 31, 2015 and 2014 , 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 January 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-01, which amends FASB Accounting Standards Codification ("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. 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 November 2015, the FASB issued ASU No. 2015-17, which amends ASC Topic 740, "Income Taxes". The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. PacifiCorp early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in current deferred income tax assets of $28 million and noncurrent deferred income tax liabilities of $28 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted, and must be adopted retrospectively for each period presented to reflect the new guidance. PacifiCorp early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets of $34 million and long-term debt of $34 million as of December 31, 2014. 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. 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.
MidAmerican Energy Company [Member]
Allowance for Doubtful Accounts [Line Items]
Summary of Significant Accounting Policies [Text Block]	Summary of Significant Accounting Policies 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 investments and nonregulated property, net 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, 2015 and 2014 , the allowance for doubtful accounts totaled $6 million and $7 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 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 Statements of Operations as nonregulated operating revenue for sales contracts and as nonregulated cost of sales for purchase contracts and electricity and natural gas swap contracts. 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. MidAmerican Energy 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 materials and supplies, totaling $105 million and $101 million as of December 31, 2015 and 2014 , respectively, coal stocks, totaling $102 million and $54 million as of December 31, 2015 and 2014 , respectively, and natural gas in storage, totaling $27 million and $24 million as of December 31, 2015 and 2014 , 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 $8 million and $41 million higher as of December 31, 2015 and 2014 , 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. 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, 2015 and 2014 , unbilled revenue was $138 million and $131 million , respectively, and is included in receivables, net on the Balance Sheets. The determination of revenue from an individual customer is based on a systematic reading of meters and 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 compared to normal, total volumes supplied to the system, line losses, economic impacts and composition of customer classes. Estimates are reversed in the following month and actual revenue is recorded based on 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 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, 2015 and 2014 , was $17 million and $25 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, and substantially all of their respective currently payable or receivable income taxes are remitted to or received from BHE. 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, 2015 and 2014 , these amounts were recognized as a net regulatory asset totaling $858 million and $730 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 January 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-01, which amends FASB Accounting Standards Codification ("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 November 2015, the FASB issued ASU No. 2015-17, which amends FASB ASC Topic 740, "Income Taxes." The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. MidAmerican Energy early adopted this guidance as of December 31, 2015, under a retrospective method, resulting in a decrease of $1 million each in other current assets and noncurrent deferred income tax liabilities as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. MidAmerican Energy early adopted this guidance as of December 31, 2015, under a retrospective method, resulting in a decrease of $22 million each in other assets and long-term debt as of December 31, 2014. 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. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016. Early application is not permitted. 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 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 2015 , 2014 and 2013 , 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. 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 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): 2015 2014 2013 Beginning balance $ 14 $ 8 $ 8 Charged to operating costs and expenses, net 16 14 15 Write-offs, net (17 ) (8 ) (15 ) Ending balance $ 13 $ 14 $ 8 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 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. Inventories Inventories consist mainly of materials and supplies totaling $58 million as of December 31 , 2015 and 2014 , and fuel, which includes coal stock, stored natural gas and fuel oil, totaling $22 million and $30 million as of December 31 , 2015 and 2014 , 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 cost of removal 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, 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, 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 2015 and 2014 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. Management's methodology to assess its legal obligation includes an inventory of assets by Nevada Power 's system and components and a review of rights-of-way and easements, regulatory orders, leases and federal, state and local environmental laws. Additionally, management has determined evaporative ponds, dry ash landfills, fuel storage tanks, asbestos and oils treated with Poly Chlorinated Biphenyl have met the requirements for an ARO. 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 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. As substantially all property, plant and equipment was used in regulated businesses as of December 31 , 2015 , 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 , 2015 and 2014 , these amounts were recognized as regulatory assets of $149 million and $156 million , respectively, and regulatory liabilities of $10 million and $3 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 , 2015 and 2014 , unbilled revenue was $116 million and $111 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 using the effective interest method. Segment Information Nevada Power currently has one segment, which includes its regulated electric utility operations. New Accounting Pronouncements In November 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2015-17, which amends FASB Accounting Standards Codification ("ASC") Topic 740, "Income Taxes". The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. Nevada Power early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in current deferred income tax assets and noncurrent deferred income tax liabilities of $145 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. Nevada Power early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets and long-term debt of $32 million as of December 31, 2014. 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. 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.
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. 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 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): 2015 2014 2013 Beginning balance $ 2 $ 1 $ 1 Charged to operating costs and expenses, net 1 2 2 Write-offs, net (2 ) (1 ) (2 ) Ending balance $ 1 $ 2 $ 1 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 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. Inventories Inventories consist mainly of materials and supplies totaling $34 million and $32 million as of December 31 , 2015 and 2014 , respectively, and fuel, which includes coal stock, stored natural gas and fuel oil, totaling $5 million and $8 million as of December 31 , 2015 and 2014 , 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 cost of removal 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, 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, 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 2015 and 2014 was 7.62% and 7.58% for electric, 5.97% and 4.96% for natural gas and 7.44% and 7.28% for common facilities, respectively. 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. Management's methodology to assess its legal obligation includes an inventory of assets by Sierra Pacific 's system and components and a review of rights-of-way and easements, regulatory orders, leases and federal, state and local environmental laws. Additionally, management has determined evaporative ponds, dry ash landfills, fuel storage tanks, asbestos and oils treated with Poly Chlorinated Biphenyl have met the requirements for an ARO. 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 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. As substantially all property, plant and equipment was used in regulated businesses as of December 31 , 2015 , 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 , 2015 and 2014 , these amounts were recognized as regulatory assets of $90 million and $94 million , respectively, and regulatory liabilities of $7 million and $8 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 , 2015 and 2014 , unbilled revenue was $59 million and $57 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 allocate the natural gas sales between generation and natural gas retail. 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 using the effective interest method. New Accounting Pronouncements In November 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2015-17, which amends FASB Accounting Standards Codification ("ASC") Topic 740, "Income Taxes". The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. Sierra Pacific early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in current deferred income tax assets and noncurrent deferred income tax liabilities of $42 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. Sierra Pacific early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets and long-term debt of $10 million as of December 31, 2014. 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. 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.

Business Acquisitions (Notes)

Business Acquisitions (Notes)	12 Months Ended
	Dec. 31, 2015
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 2015 , 2014 and 2013 . 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 8,100 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"). The transaction was approved by both the SNC-Lavalin and BHE boards of directors in May 2014. In June 2014, an Advance Ruling Certificate was received from the Commissioner of Competition, providing clearance for the AltaLink acquisition. In July 2014, the Canadian Minister of Industry approved the transaction under the Investment Canada Act, determining that the AltaLink Transaction constitutes a net benefit to Canada. In November 2014, approval by the AUC was received. In connection with the approval of the transaction under the Investment Canada Act, various commitments were made to the Canadian Minister of Industry. The commitments included, among others: • AltaLink will remain locally managed and incorporated under the laws of Canada, with its headquarters, senior management team and operations located in Alberta. • AltaLink's independent board of directors will continue to be comprised of a majority of Canadians. • There will be no reductions in employment levels at AltaLink as a result of the transaction. • Reinvest 100% of AltaLink’s earnings back into AltaLink, elsewhere in Alberta or other regions of Canada for five years. This commitment will support AltaLink’s C$2.7 billion investment in Alberta's energy infrastructure planned over the next three years, subject to continued oversight by the AUC and the Alberta Electric System Operator. • Spend at least C$27 million to pursue joint development opportunities with Canadian partners in Canada and the United States. • Invest at least C$3 million of new funds to support Alberta-based academic programs focused on energy-related topics, cultural organizations and community-based programs. • Maintain AltaLink's commitment to provide C$3 million over three years in community and charitable contributions across Alberta. • Share best practices with AltaLink on safety, customer satisfaction, cybersecurity and supplier diversity at no cost. • Provide opportunities for Albertan and other Canadian companies to supply products and services to other BHE businesses. 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. Allocation of Purchase Price The operations of ALP are subject to the rate-setting authority of the AUC and are accounted for pursuant to GAAP, including the authoritative guidance for regulated operations. The rate-setting and cost recovery provisions establish rates on a cost-of-service basis designed to allow ALP an opportunity to recover its costs of providing service and a return on its investment in rate base. Except for certain assets not currently in rates, the fair value of ALP's assets acquired and liabilities assumed subject to these rate-setting provisions are assumed to approximate their carrying values and, therefore, no fair value adjustments have been reflected related to these amounts. The fair value of AltaLink's assets acquired and liabilities assumed not subject to the rate-setting provisions discussed above was determined using an income approach. This approach is based on significant estimates and assumptions, including Level 3 inputs, which are judgmental in nature. The estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting the risk inherent in the future cash flows and future market prices. AltaLink's non-regulated assets acquired and liabilities assumed consist principally of AltaLink Investments, L.P.'s and AltaLink Holdings, L.P.'s senior bonds and debentures. The fair value of these liabilities was determined based on quoted market prices. The following table summarizes the fair values of the assets acquired and liabilities assumed as of the acquisition date (in millions): Fair Value Current assets, including cash and cash equivalents of $15 $ 174 Property, plant and equipment 5,610 Goodwill 1,744 Other long-term assets 141 Total assets 7,669 Current liabilities, including current portion of long-term debt of $79 866 Subsidiary debt, less current portion 3,772 Deferred income taxes 85 Other long-term liabilities 218 Total liabilities 4,941 Net assets acquired $ 2,728 During 2015, the Company made revisions to certain assets not currently in rates, the fair value of certain contracts and certain contingencies based upon the receipt of additional information about the facts and circumstances that existed as of the acquisition date. Provisional amounts were subject to further revision for up to 12 months following the acquisition date until the related valuations were completed. Goodwill The excess of the purchase price paid over the estimated fair values of the identifiable assets acquired and liabilities assumed totaled $1.7 billion and is reflected as goodwill in the BHE Transmission reportable segment. The goodwill reflects the value for the opportunities to invest in Alberta's electric transmission infrastructure and to develop solutions to meet the long-term energy needs of Alberta. Goodwill is not amortized, but rather is reviewed annually for impairment or more frequently if indicators of impairment exist. None of the goodwill recognized is deductible for income tax purposes, and no deferred income taxes have been recorded related to the goodwill. 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 2013 Operating revenue $ 17,888 $ 13,130 Net income attributable to BHE shareholders $ 2,155 $ 1,667 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. NV Energy, Inc. Transaction Description On December 19, 2013, BHE completed the merger contemplated by the Agreement and Plan of Merger dated May 29, 2013, among BHE , Silver Merger Sub, Inc. ("Merger Sub"), BHE 's wholly-owned subsidiary, and NV Energy, Inc. ("NV Energy"), whereby Merger Sub was merged into NV Energy and NV Energy became an indirect wholly-owned subsidiary of BHE ("NV Energy Transaction"). BHE funded the total purchase price of $5.6 billion , or $23.75 per share for 100% of NV Energy’s outstanding common stock, by issuing $1.0 billion of common stock on December 19, 2013, issuing $2.6 billion of junior subordinated debentures to certain Berkshire Hathaway subsidiaries on December 19, 2013, and using $2.0 billion of cash, including certain proceeds from BHE 's $2.0 billion senior debt issuance on November 8, 2013. NV Energy owns two regulated public utilities, Nevada Power and Sierra Pacific (together, the "Nevada Utilities"), that provide electric service to 1.2 million regulated retail electric customers and 0.2 million regulated retail natural gas customers in Nevada. Included in BHE 's Consolidated Statement of Operations within the NV Energy reportable segment for the year ended December 31, 2013 are costs totaling $38 million , consisting of $22 million for amounts payable under NV Energy's change in control policy and $16 million for donations to NV Energy's charitable foundation, and a $20 million one-time bill credit to retail customers included as a reduction to operating revenue. Additionally, BHE incurred $5 million of direct transaction costs associated with the NV Energy Transaction that are included in operating expense on the Consolidated Statement of Operations for the year ended December 31, 2013. Pro Forma Financial Information The following unaudited pro forma financial information reflects the consolidated results of operations of BHE , non-recurring transaction, integration and other costs incurred by both BHE and NV Energy during 2013 totaling $74 million , after-tax, a one-time bill credit to retail customers of $13 million , after-tax, and the amortization of the purchase price adjustments each assuming the acquisition had taken place on January 1, 2012 (in millions): 2013 Operating revenue $ 15,561 Net income attributable to BHE shareholders $ 1,867 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 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. In 2013, the Company completed various other acquisitions of residential real estate brokerage and mortgage businesses totaling $240 million . The purchase prices were allocated to the assets acquired and liabilities assumed in each acquisition. The assets acquired consisted of loans receivable and other working capital items, goodwill of $188 million and other identifiable intangible assets. The liabilities assumed totaled $271 million primarily related to mortgage lines of credit secured by the loans receivable acquired and other working capital items.

Property, Plant and Equipment,

Property, Plant and Equipment, Net (Notes)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 Regulated assets: Utility generation, transmission and distribution systems 5-80 years $ 69,248 $ 64,645 Interstate natural gas pipeline assets 3-80 years 6,755 6,660 76,003 71,305 Accumulated depreciation and amortization (22,682 ) (21,447 ) Regulated assets, net 53,321 49,858 Nonregulated assets: Independent power plants 5-30 years 4,751 4,362 Other assets 3-30 years 875 673 5,626 5,035 Accumulated depreciation and amortization (805 ) (839 ) Nonregulated assets, net 4,821 4,196 Net operating assets 58,142 54,054 Construction work-in-progress 2,627 5,194 Property, plant and equipment, net $ 60,769 $ 59,248 Construction work-in-progress includes $2.3 billion and $4.3 billion as of December 31, 2015 and 2014 , respectively, related to the construction of regulated assets. PacifiCorp revised its depreciation rates effective January 1, 2014 based on results of a depreciation study approved by its state regulatory commissions. The approved depreciation rates resulted in an increase in depreciation expense of $35 million for the year ended December 31, 2014 as compared to the year ended December 31, 2013. During the third quarter of 2013, MidAmerican Energy revised its depreciation rates for certain electric generating facilities based on the results of a new depreciation study. The new rates reflect longer estimated useful lives for wind-powered generating facilities placed in-service in 2011 and 2012 and a lower accrual rate for the cost of removal regulatory liability related to coal-fueled generating facilities. The effect of this change was to reduce depreciation and amortization expense by $20 million in 2013 and $49 million annually based on depreciable plant balances at the time of the change. Effective January 1, 2014, MidAmerican Energy revised depreciation rates for certain electric generating facilities based on the results of its 2013 Iowa electric retail rate case. The new depreciation rates reflect longer estimated useful lives for certain generating facilities. The effect of this change was to reduce depreciation and amortization expense by $50 million annually based on depreciable plant balances at the time of the change.
MidAmerican Funding LLC [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net [Text Block]	Property, Plant and Equipment, Net Refer to Note 3 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, 2015 and 2014 and related accumulated depreciation and amortization of $8 million as of December 31, 2015 and 2014 , 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 2015 2014 Utility plant in service: Generation 20-100 years $ 10,404 $ 9,351 Transmission 52-70 years 1,305 1,142 Electric distribution 20-70 years 3,059 2,933 Gas distribution 28-70 years 1,507 1,432 Utility plant in service 16,275 14,858 Accumulated depreciation and amortization (5,229 ) (4,954 ) Utility plant in service, net 11,046 9,904 Nonregulated property, net: Nonregulated property gross 5-45 years 15 14 Accumulated depreciation and amortization (5 ) (5 ) Nonregulated property, net 10 9 11,056 9,913 Construction work in progress 667 606 Property, plant and equipment, net $ 11,723 $ 10,519 Nonregulated property includes land, computer software and other assets not recoverable for regulated utility purposes. The average depreciation and amortization rates applied to depreciable utility plant for the years ended December 31 were as follows: 2015 2014 2013 Electric 3.0 % 2.8 % 3.3 % Gas 2.9 % 2.8 % 2.8 % During the third quarter of 2013, MidAmerican Energy revised its depreciation rates for certain electric generating facilities based on the results of a new depreciation study. The new rates reflect longer estimated useful lives for wind-powered generating facilities placed in service in 2011 and 2012 and a lower accrual rate for the cost of removal regulatory liability related to coal-fueled generating facilities. The effect of this change was to reduce depreciation and amortization expense by $20 million in 2013 and $49 million annually based on depreciable plant balances at the time of the change. Effective January 1, 2014, MidAmerican Energy revised depreciation rates for certain electric generating facilities based on the results of its 2013 Iowa electric retail rate case. The new depreciation rates reflect longer estimated useful lives for certain generating facilities. The effect of this change was to reduce depreciation and amortization expense by $50 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 2015 2014 Property, plant and equipment: Generation 10 - 67 years $ 12,164 $ 11,932 Transmission 58 - 75 years 5,914 5,392 Distribution 20 - 70 years 6,408 6,197 Intangible plant (1) 5 - 62 years 875 879 Other 5 - 60 years 1,396 1,413 Property, plant and equipment in-service 26,757 25,813 Accumulated depreciation and amortization (8,360 ) (8,026 ) Net property, plant and equipment in-service 18,397 17,787 Construction work-in-progress 629 932 Total property, plant and equipment, net $ 19,026 $ 18,719 (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% , 3.0% and 2.8% for the years ended December 31, 2015 , 2014 and 2013 , respectively. Depreciation Study PacifiCorp revised its depreciation rates effective January 1, 2014 based on results of a depreciation study approved by its state regulatory commissions. The approved depreciation rates resulted in an increase in depreciation expense of $35 million for the year ended December 31, 2014 as compared to the year ended December 31, 2013. 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 $155 million and $143 million as of December 31, 2015 and 2014 , respectively, and accumulated depreciation of $112 million and $107 million as of December 31, 2015 and 2014 , 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 2015 2014 Utility plant: Generation 25 - 80 years $ 4,212 $ 4,034 Distribution 20 - 65 years 3,118 3,018 Transmission 45 - 65 years 1,788 1,757 General and intangible plant 5 - 65 years 694 669 Utility plant 9,812 9,478 Accumulated depreciation and amortization (2,971 ) (2,599 ) Utility plant, net 6,841 6,879 Other non-regulated, net of accumulated depreciation and amortization 5 - 65 years 2 4 Plant, net 6,843 6,883 Construction work-in-progress 153 120 Property, plant and equipment, net $ 6,996 $ 7,003 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 , 2015 , 2014 and 2013 was 3.0% , 3.3% 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. Impairment of Regulated Assets Not In Rates Nevada Power recorded an impairment charge of $29 million and $31 million in operating and maintenance on the Consolidated Statements of Operations for the years ended December 31 , 2014 and 2013, respectively, related to the recovery of certain assets not currently in rates. Included in the 2014 impairment is $19 million related to the settlement of the 2014 general rate case. Impairment of regulated assets not in rates were not material in 2015.
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 2015 2014 Utility plant: Electric generation 40 - 125 years $ 1,134 $ 1,036 Electric distribution 20 - 70 years 1,382 1,321 Electric transmission 50 - 70 years 739 719 Electric general and intangible plant 5 - 65 years 139 123 Natural gas distribution 40 - 70 years 374 366 Natural gas general and intangible plant 8 - 10 years 13 13 Common general 5 - 65 years 265 234 Utility plant 4,046 3,812 Accumulated depreciation and amortization (1,368 ) (1,300 ) Utility plant, net 2,678 2,512 Construction work-in-progress 88 128 Property, plant and equipment, net $ 2,766 $ 2,640 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 , 2015 , 2014 and 2013 was 2.9% , 3.0% 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. Impairment of Regulated Assets Not In Rates Sierra Pacific recorded an impairment charge of $12 million and $4 million in operating and maintenance on the Consolidated Statements of Operations for the years ended December 31 , 2014 and 2013, respectively, related to the recovery of certain assets not currently in rates. Included in the 2014 impairment is $8 million related to the settlement of the "companion filing" in the 2014 Nevada Power general rate case. Impairment of regulated assets not in rates were not material in 2015.

Jointly Owned Utility Facilitie

Jointly Owned Utility Facilities (Notes)	12 Months Ended
	Dec. 31, 2015
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, 2015 (dollars in millions): Accumulated Construction Company Facility In Depreciation and Work-in- Share Service Amortization Progress PacifiCorp: Jim Bridger Nos. 1-4 67 % $ 1,289 $ 566 $ 83 Hunter No. 1 94 469 154 — Hunter No. 2 60 293 94 — Wyodak 80 457 198 3 Colstrip Nos. 3 and 4 10 239 128 2 Hermiston (1) 50 177 71 1 Craig Nos. 1 and 2 19 325 213 18 Hayden No. 1 25 76 30 — Hayden No. 2 13 30 18 7 Foote Creek 79 39 24 — Transmission and distribution facilities Various 577 178 46 Total PacifiCorp 3,971 1,674 160 MidAmerican Energy: Louisa No. 1 88 % 757 405 7 Quad Cities Nos. 1 and 2 (2) 25 672 340 27 Walter Scott, Jr. No. 3 79 608 297 6 Walter Scott, Jr. No. 4 (3) 60 448 91 — George Neal No. 4 41 305 148 1 Ottumwa No. 1 52 554 184 3 George Neal No. 3 72 415 153 — Transmission facilities Various 245 83 2 Total MidAmerican Energy 4,004 1,701 46 NV Energy: Navajo 11 % 203 141 1 Silverhawk 75 247 58 2 Valmy 50 382 209 2 Transmission facilities Various 224 39 1 Total NV Energy 1,056 447 6 BHE Pipeline Group - common facilities Various 285 158 1 Total $ 9,316 $ 3,980 $ 213 (1) PacifiCorp has contracted to purchase the remaining 50% of the output of the Hermiston generating facility. (2) Includes amounts related to nuclear fuel. (3) Facility in-service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling $319 million and $67 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, 2015 (dollars in millions): Facility Accumulated Construction PacifiCorp in Depreciation and Work-in- Share Service Amortization Progress Jim Bridger Nos. 1 - 4 67 % $ 1,289 $ 566 $ 83 Hunter No. 1 94 469 154 — Hunter No. 2 60 293 94 — Wyodak 80 457 198 3 Colstrip Nos. 3 and 4 10 239 128 2 Hermiston (1) 50 177 71 1 Craig Nos. 1 and 2 19 325 213 18 Hayden No. 1 25 76 30 — Hayden No. 2 13 30 18 7 Foote Creek 79 39 24 — Transmission and distribution facilities Various 577 178 46 Total $ 3,971 $ 1,674 $ 160 (1) As discussed in Note 17, PacifiCorp has contracted to purchase the remaining 50% of the output of the Hermiston generating facility. In October 2015, PacifiCorp and Idaho Power Company ("Idaho Power") each transferred to the other party full or undivided interests in specified transmission-related equipment and facilities under a Joint Purchase and Sale Agreement executed in October 2014. Contemporaneously with the Joint Purchase and Sale Agreement, PacifiCorp and Idaho Power executed a Joint Ownership and Operating Agreement applicable to the specified transmission-related equipment and facilities.
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, 2015 (dollars in millions): Accumulated Construction Company Plant in Depreciation and Work in Share Service Amortization Progress Louisa Unit No. 1 88.0 % $ 757 $ 405 $ 7 Quad Cities Unit Nos. 1 & 2 (1) 25.0 672 340 27 Walter Scott, Jr. Unit No. 3 79.1 608 297 6 Walter Scott, Jr. Unit No. 4 (2) 59.7 448 91 — George Neal Unit No. 4 40.6 305 148 1 Ottumwa Unit No. 1 52.0 554 184 3 George Neal Unit No. 3 72.0 415 153 — Transmission facilities (3) Various 245 83 2 Total $ 4,004 $ 1,701 $ 46 (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 $67 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 4 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 , 2015 (dollars in millions): Nevada Construction Power's Facility In Accumulated Work-in- Share Service Depreciation Progress Silverhawk Generating Station 75% $ 247 $ 58 $ 2 Navajo Generating Station 11 203 141 1 ON Line Transmission Line 24 144 8 1 Other Transmission Facilities Various 68 28 — Total $ 662 $ 235 $ 4
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 , 2015 (dollars in millions): Sierra Construction Pacific's Facility In Accumulated Work-in- Share Service Depreciation Progress Valmy Generating Station 50% $ 382 $ 209 $ 2 ON Line Transmission Line 1 8 1 — Valmy Transmission 50 4 2 — Total $ 394 $ 212 $ 2

Regulatory Matters (Notes)

Regulatory Matters (Notes)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 Deferred income taxes (1) 26 years $ 1,577 $ 1,468 Employee benefit plans (2) 9 years 778 747 Asset disposition costs (3) Various 307 329 Deferred net power costs 1 year 140 277 Asset retirement obligations 8 years 281 239 Unrealized loss on regulated derivative contracts 5 years 250 223 Abandoned projects 5 years 136 159 Unamortized contract values 8 years 110 123 Other Various 706 688 Total regulatory assets $ 4,285 $ 4,253 Reflected as: Current assets $ 130 $ 253 Noncurrent assets 4,155 4,000 Total regulatory assets $ 4,285 $ 4,253 (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) Includes amounts 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. The Company had regulatory assets not earning a return on investment of $2.3 billion and $2.6 billion as of December 31, 2015 and 2014 , 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 2015 2014 Cost of removal (1) 28 years $ 2,167 $ 2,215 Deferred net power costs 2 years 206 — Asset retirement obligations 22 years 147 169 Levelized depreciation 26 years 199 169 Employee benefit plans (2) 12 years 13 20 Other Various 301 259 Total regulatory liabilities $ 3,033 $ 2,832 Reflected as: Current liabilities $ 402 $ 163 Noncurrent liabilities 2,631 2,669 Total regulatory liabilities $ 3,033 $ 2,832 (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. Utah Mine Disposition Due to quality issues with the coal reserves at PacifiCorp's Deer Creek mine in Utah and rising costs at PacifiCorp's wholly owned subsidiary, Energy West Mining Company, PacifiCorp believes the Deer Creek coal reserves are no longer able to be economically mined. As a result, 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 April 2015, PacifiCorp filed all-party settlement stipulations with the UPSC and the WPSC finding that the decision to enter into the Utah Mine Disposition transaction was prudent and in the public interest. The UPSC approved the stipulation in April 2015 and the WPSC approved the stipulation in May 2015. In May 2015, the OPUC issued its final order concluding that the Utah Mine Disposition transaction produces net benefits for customers and was in the public interest. The IPUC also issued an order in May 2015, approving the Utah Mine Disposition and ruling that the decision to enter into the transaction was prudent and in the public interest. Accordingly, in June 2015, PacifiCorp sold the specified Utah mining assets and the replacement and amended coal supply agreements became effective. Refer to Note 12 for discussion of the UMWA 1974 Pension Plan withdrawal and the settlement of the other postretirement benefit obligation for UMWA participants. The Deer Creek mine is currently idled and closure activities have begun. In December 2014, PacifiCorp also filed an advice letter with the California Public Utilities Commission ("CPUC"). 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.
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 2015 2014 Deferred income taxes (1) 26 years $ 437 $ 446 Employee benefit plans (2) 8 years 499 491 Utah mine disposition (3) Various 186 194 Unamortized contract values 8 years 110 123 Deferred net power costs 1 year 86 122 Unrealized loss on derivative contracts 5 years 133 85 Other Various 234 244 Total regulatory assets $ 1,685 $ 1,705 Reflected as: Current assets $ 102 $ 131 Noncurrent assets 1,583 1,574 Total regulatory assets $ 1,685 $ 1,705 (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 $1.102 billion and $1.505 billion as of December 31, 2015 and 2014 , 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 2015 2014 Cost of removal (1) 26 years $ 894 $ 873 Deferred income taxes Various 12 13 Other Various 66 58 Total regulatory liabilities $ 972 $ 944 Reflected as: Current liabilities $ 34 $ 34 Noncurrent liabilities 938 910 Total regulatory liabilities $ 972 $ 944 (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 Due to quality issues with the coal reserves at PacifiCorp's Deer Creek mine in Utah and rising costs at PacifiCorp's wholly owned subsidiary, Energy West Mining Company, PacifiCorp believes the Deer Creek coal reserves are no longer able to be economically mined. As a result, 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 April 2015, PacifiCorp filed all-party settlement stipulations with the UPSC and the WPSC finding that the decision to enter into the Utah Mine Disposition transaction was prudent and in the public interest. The UPSC approved the stipulation in April 2015 and the WPSC approved the stipulation in May 2015. In May 2015, the OPUC issued its final order concluding that the Utah Mine Disposition transaction produces net benefits for customers and was in the public interest. The IPUC also issued an order in May 2015, approving the Utah Mine Disposition and ruling that the decision to enter into the transaction was prudent and in the public interest. Accordingly, in June 2015, PacifiCorp sold the specified Utah mining assets and the replacement and amended coal supply agreements became effective. Refer to Note 9 for discussion of the UMWA 1974 Pension Plan withdrawal and the settlement of the other postretirement benefit obligation for UMWA participants. The Deer Creek mine is currently idled and closure activities have begun. In December 2014, PacifiCorp also filed an advice letter with the California Public Utilities Commission ("CPUC"). 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.
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 2015 2014 Deferred income taxes, net (1) 25 years $ 858 $ 730 Asset retirement obligations (2) 6 years 94 62 Employee benefit plans (3) 11 years 39 42 Unrealized loss on regulated derivative contracts 1 year 20 38 Other Various 33 36 Total $ 1,044 $ 908 (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 11 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 $1.0 billion and $904 million as of December 31, 2015 and 2014 , 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 2015 2014 Cost of removal accrual (1) 25 years $ 653 $ 642 Asset retirement obligations (2) 22 years 140 159 Other Various 38 36 Total $ 831 $ 837 (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 11 for a discussion of asset retirement obligations.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Schedule Of Regulatory Assets and Liabilities [Line Items]
Regulatory Matters [Text Block]	Regulatory Matters Refer to Note 5 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 2015 2014 Deferred income taxes (1) 28 years $ 149 $ 156 Merger costs from 1999 merger 28 years 143 149 Decommissioning costs 7 years 121 113 Employee benefit plans (2) 10 years 98 85 Abandoned projects 4 years 91 107 Deferred operating costs 20 years 87 61 Asset retirement obligations 7 years 79 80 Legacy meters 17 years 64 68 Deferred energy costs 2 years 56 129 Other Various 169 178 Total regulatory assets $ 1,057 $ 1,126 Reflected as: Current assets $ — $ 57 Other assets 1,057 1,069 Total regulatory assets $ 1,057 $ 1,126 (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 $572 million and $788 million as of December 31 , 2015 and 2014 , respectively, related to deferred income taxes, merger costs from 1999 merger, asset retirement obligations, deferred operating costs, deferred excess energy costs, loss on reacquired debt, unrealized loss on regulated derivative contracts and a portion of abandoned projects. Regulatory assets not earning a return as of December 31, 2014 also included legacy meters. 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 2015 2014 Cost of removal (1) 34 years $ 273 $ 295 Deferred energy costs 2 years 139 — Energy efficiency program 1 year 34 25 Other Various 31 46 Total regulatory liabilities $ 477 $ 366 Reflected as: Current liabilities $ 173 $ 40 Other long-term liabilities 304 326 Total regulatory liabilities $ 477 $ 366 (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 is 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 Implementation Rates and Energy Efficiency Program Rates The PUCN authorizes an electric utility to recover lost revenue that is attributable to the measurable and verifiable effects associated with the implementation of efficiency and conservation programs approved by the PUCN through energy efficiency implementation rates ("EEIR"). As a result, Nevada Power files annually to adjust energy efficiency program rates ("EEPR") and EEIR for over- or under-collected balances, which are effective in October of the same year. The PUCN's final order approving the BHE Merger stipulated that Nevada Power will not seek recovery of any lost revenue for calendar year 2013 and, for the calendar year 2014 in an amount that exceeds 50% of the lost revenue that Nevada Power could otherwise request. In February 2014, Nevada Power filed an application with the PUCN to reset the EEIR and EEPR. In June 2014, the PUCN accepted a stipulation to adjust the EEIR, as of July 1, 2014, to collect 50% of the estimated lost revenue that Nevada Power would otherwise be allowed to recover for the 2014 calendar year. The EEIR was effective from July through December 2014 and reset on January 1, 2015 and was in effect through September 2015. In February 2015, Nevada Power filed an application to reset the EEIR and EEPR. In August 2015, the PUCN accepted a stipulation for Nevada Power to calculate the base EEIR using a revised methodology for calculating lost revenue and for Nevada Power to make a $5 million reduction to the EEPR revenue requirement to more accurately reflect the actual level of spending and to minimize any over collection from its customers. The reset of the EEIR and EEPR was effective October 1, 2015 and remains in effect through September 30, 2016. 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 collected. The current EEIR liability for Nevada Power is $18 million and $11 million , which is included in current regulatory liabilities on the Consolidated Balance Sheets as of December 31 , 2015 and 2014 , respectively. General Rate Case In May 2014, Nevada Power filed a general rate case with the PUCN. In July 2014, Nevada Power made its certification filing, which requested incremental annual revenue relief in the amount of $38 million , or an average price increase of 2% . In October 2014, Nevada Power reached a settlement agreement with certain parties agreeing to a zero increase in the revenue requirement. In October 2014, the PUCN issued an order in the general rate case filing that accepted the settlement. The order provides for increases in the fixed-monthly service charge for customers with a corresponding decrease in the base tariff general rate effective January 1, 2015. As a result of the order, Nevada Power recorded $15 million in asset impairments related to property, plant and equipment and $5 million of regulatory asset impairments, which are included in operating and maintenance on the Consolidated Statements of Operations for the year ended December 31, 2014. Additionally, Nevada Power recorded a $5 million gain in other, net on the Consolidated Statement of Operations for the year ended December 31 , 2014 related to the disposition of property. In October 2014, a party filed a petition for reconsideration of the PUCN order. In November 2014, the PUCN granted the petition for reconsideration and reaffirmed the order issued in October 2014. 2013 FERC Transmission Rate Case In May 2013, the Nevada Utilities , filed an application with the FERC to establish single system transmission and ancillary service rates. The combined filing requested incremental rate relief of $17 million annually to be effective January 1, 2014. In August 2013, the FERC granted the companies' request for a rate effective date of January 1, 2014 subject to refund, and set the case for hearing or settlement discussions. On January 1, 2014, Nevada Power implemented the filed rates in this case subject to refund as set forth in the FERC's order. In September 2014, the Nevada Utilities , filed an unopposed settlement offer with the FERC on behalf of NV Energy and the intervening parties providing rate relief of $4 million . The settlement offer would resolve all outstanding issues related to this case. In addition, a preliminary order from the administrative law judge granting the motion for interim rate relief was issued, which authorizes Nevada Power to institute the interim rates effective September 1, 2014, and begin billing transmission customers under the settlement rates for service provided on and after that date. In January 2015, the FERC approved the settlement and refunds were issued.
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 2015 2014 Employee benefit plans (2) 10 years $ 126 $ 115 Deferred income taxes (1) 28 years 90 94 Merger costs from 1999 merger 31 years 83 87 Abandoned projects 9 years 44 51 Deferred energy costs 2 years — 32 Loss on reacquired debt 17 years 22 24 Other Various 67 73 Total regulatory assets $ 432 $ 476 Reflected as: Current assets $ — $ 32 Other assets 432 444 Total regulatory assets $ 432 $ 476 (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. Sierra Pacific had regulatory assets not earning a return on investment of $254 million and $269 million as of December 31 , 2015 and 2014 , respectively. In 2015 the regulatory assets not earning a return on investment consist of deferred income taxes, merger costs from 1999 merger, loss 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 2015 2014 Cost of removal (1) 40 years $ 208 $ 233 Deferred energy costs 2 years 66 — Renewable energy program 1 year 8 32 Other Various 26 36 Total regulatory liabilities $ 308 $ 301 Reflected as: Current liabilities $ 78 $ 39 Other long-term liabilities 230 262 Total regulatory liabilities $ 308 $ 301 (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 is 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 Implementation Rates and Energy Efficiency Program Rates The PUCN authorizes an electric utility to recover lost revenue that is attributable to the measurable and verifiable effects associated with the implementation of efficiency and conservation programs approved by the PUCN through energy efficiency implementation rates ("EEIR"). As a result, Sierra Pacific files annually to adjust energy efficiency program rates ("EEPR") and EEIR for over- or under-collected balances, which are effective in October of the same year. The PUCN's final order approving the BHE Merger stipulated that Sierra Pacific will not seek recovery of any lost revenue for calendar year 2013 and, for the calendar year 2014 in an amount that exceeds 50% of the lost revenue that Sierra Pacific could otherwise request. In February 2014, Sierra Pacific filed an application with the PUCN to reset the EEIR and EEPR. In June 2014, the PUCN accepted a stipulation to adjust the EEIR, as of July 1, 2014, to collect 50% of the estimated lost revenue that Sierra Pacific would otherwise be allowed to recover for the 2014 calendar year. The EEIR was effective from July through December 2014 and reset on January 1, 2015 and was in effect through September 2015. In February 2015, Sierra Pacific filed an application to reset the EEIR and EEPR. In August 2015, the PUCN accepted a stipulation for Sierra Pacific to calculate the base EEIR using a revised methodology for calculating lost revenue and for Sierra Pacific to make a $1 million reduction to the EEPR revenue requirement to more accurately reflect the actual level of spending and to minimize any over collection from its customers. The reset of the EEIR and EEPR was effective October 1, 2015 and remains in effect through September 30, 2016. 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 collected. The current EEIR liability for Sierra Pacific is $3 million and $2 million , which is included in current regulatory liabilities on the Consolidated Balance Sheets as of December 31 , 2015 and 2014 , respectively. General Rate Case In connection with Nevada Power 's general rate case filing in May 2014, as required by the PUCN, Sierra Pacific made a "companion filing" for the purpose of documenting the costs and benefits of Sierra Pacific 's investment in the advanced service delivery program. In October 2014, the PUCN issued an order in the companion filing issued with the general rate case order that, among other things, provided for the implementation of new rates effective January 1, 2015 to begin recovery of costs associated with advance service delivery. The recovery of advanced service delivery costs will increase annual revenue approximately $10 million . As a result of the PUCN order in the companion filing issued with the Nevada Power general rate case order, Sierra Pacific recorded $7 million in asset impairments related to property, plant and equipment and $1 million of regulatory asset impairments, which are included in operating and maintenance on the Consolidated Statements of Operations for the year ended December 31, 2014. 2013 FERC Transmission Rate Case In May 2013, the Nevada Utilities , filed an application with the FERC to establish single system transmission and ancillary service rates. The combined filing requested incremental rate relief of $17 million annually to be effective January 1, 2014. In August 2013, the FERC granted the companies' request for a rate effective date of January 1, 2014 subject to refund, and set the case for hearing or settlement discussions. On January 1, 2014, Sierra Pacific implemented the filed rates in this case subject to refund as set forth in the FERC's order. In September 2014, the Nevada Utilities , filed an unopposed settlement offer with the FERC on behalf of NV Energy and the intervening parties providing rate relief of $4 million . The settlement offer would resolve all outstanding issues related to this case. In addition, a preliminary order from the administrative law judge granting the motion for interim rate relief was issued, which authorizes Sierra Pacific to institute the interim rates effective September 1, 2014, and begin billing transmission customers under the settlement rates for service provided on and after that date. In January 2015, the FERC approved the settlement and refunds were issued.

Investments and Restricted Cash

Investments and Restricted Cash and Investments (Notes)	12 Months Ended
	Dec. 31, 2015
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): 2015 2014 Investments: BYD Company Limited common stock $ 1,238 $ 881 Rabbi trusts 380 386 Other 130 126 Total investments 1,748 1,393 Equity method investments: Electric Transmission Texas, LLC 585 515 Bridger Coal Company 190 192 BHE Renewables tax equity investments 168 — Other 160 161 Total equity method investments 1,103 868 Restricted cash and investments: Quad Cities Station nuclear decommissioning trust funds 429 424 Solar Star and Topaz Projects 95 66 Other 129 167 Total restricted cash and investments 653 657 Total investments and restricted cash and investments $ 3,504 $ 2,918 Reflected as: Current assets $ 137 $ 115 Noncurrent assets 3,367 2,803 Total investments and restricted cash and investments $ 3,504 $ 2,918 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 $1.0 billion and $649 million as of December 31, 2015 and 2014 , 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. 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): 2015 2014 Nuclear decommissioning trust $ 429 $ 424 Rabbi trusts 175 175 Auction rate securities 26 26 Other 4 — Total $ 634 $ 625 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, 2015 and 2014 , the fair value of the trust's funds was invested as follows: 56% and 56% , respectively, in domestic common equity securities, 31% and 32% , respectively, in United States government securities, 9% and 9% , respectively, in domestic corporate debt securities and 4% and 3% , 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 has investments in interest bearing auction rate securities with a par value of $35 million as of December 31, 2015 and 2014 , and remaining maturities of 2 to 20 years. MidAmerican Energy considers the securities to be temporarily impaired, except for an other-than-temporary impairment of $3 million , after-tax, recorded in 2008, and has recorded unrealized losses on the securities of $3 million and $3 million , after tax, in AOCI as of December 31, 2015 and 2014 , respectively. MidAmerican Energy does not intend to sell or expect to be required to sell the securities until the remaining principal investment is collected.
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 6 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, 2015 and 2014 .

Short-Term Debt and Credit Faci

Short-Term Debt and Credit Facilities (Notes)	12 Months Ended
	Dec. 31, 2015
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) 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 2014: Credit facilities $ 2,000 $ 1,200 $ 609 $ 650 $ 265 $ 1,119 $ 853 $ 6,696 Less: Short-term debt (395 ) (20 ) (50 ) — (215 ) (251 ) (514 ) (1,445 ) Tax-exempt bond support and letters of credit (28 ) (398 ) (195 ) — — (4 ) — (625 ) Net credit facilities $ 1,577 $ 782 $ 364 $ 650 $ 50 $ 864 $ 339 $ 4,626 (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, 2015 , the Company was in compliance with the covenants of its credit facilities and letter of credit arrangements. BHE BHE has a $1.4 billion senior unsecured credit facility expiring in June 2017 and a $600 million senior unsecured credit facility expiring in June 2017. These credit facilities have a variable interest rate based on the London Interbank Offered Rate ("LIBOR") or a base rate, at BHE 's option, plus a spread that varies based on BHE 's credit ratings for its senior unsecured long-term debt securities. These credit facilities are for general corporate purposes and also support BHE 's commercial paper program and provide for the issuance of letters of credit. As of December 31, 2015 and 2014 , the weighted average interest rate on commercial paper borrowings outstanding was 0.66% and 0.49% , respectively. These credit facilities require 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, 2015 and 2014 , BHE had $142 million and $125 million , respectively, of letters of credit outstanding, of which $51 million and $28 million as of December 31, 2015 and 2014 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 2016. PacifiCorp PacifiCorp has a $600 million unsecured credit facility expiring in June 2017 and a $600 million unsecured credit facility expiring in March 2018. 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, 2015 and 2014 , the weighted average interest rate on commercial paper borrowings outstanding was 0.65% and 0.43% , 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, 2015 and 2014 , PacifiCorp had $310 million and $451 million , respectively, of fully available letters of credit issued under committed arrangements, of which $10 million and $270 million as of December 31, 2015 and 2014 were issued under the credit facilities. These letters of credit support PacifiCorp's variable-rate tax-exempt bond obligations and expire through March 2017. MidAmerican Funding 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 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, 2014 , the weighted average interest rate on commercial paper borrowings outstanding was 0.35% . 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. 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. As of December 31, 2014 , $184 million was outstanding under the credit facility, with a weighted average interest rate of 1.75% . 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. Additionally, as of December 31, 2014 , Northern Powergrid had $31 million drawn on uncommitted bank facilities totaling £42 million , with a weighted average interest rate of 2.0% . AltaLink ALP has a C$750 million secured revolving credit facility expiring in December 2017, which provides support for borrowings under the unsecured commercial paper program and may also be used for general corporate purposes. The credit facility 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 2017, which may be used for general corporate purposes, capital expenditures and letters of credit. The credit facility 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, 2015 and 2014 , ALP had $324 million and $104 million outstanding under these facilities at a weighted average interest rate of 0.85% and 1.26% , respectively. AltaLink Investments, L.P. has a C$300 million unsecured revolving term credit facility expiring in December 2020, which may be used for operating expenses, capital expenditures, working capital needs and letters of credit to a maximum of C$10 million . The credit facility 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 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 facility requires 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, 2015 and 2014 , AltaLink Investments, L.P. had $77 million and $147 million outstanding under this facility at a weighted average interest rate of 0.89% and 1.30% , 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, 2014 , HomeServices had $243 million outstanding under its credit facility with a weighted average interest rate of 1.41% . Through its subsidiaries, HomeServices maintains mortgage lines of credit totaling $578 million and $503 million as of December 31, 2015 and 2014 , respectively, used for mortgage banking activities that expire beginning in February 2016 through December 2016 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, 2015 and 2014 , HomeServices had $300 million and $271 million , respectively, outstanding under these mortgage lines of credit at a weighted average interest rate of 2.42% and 2.25% , 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 $646 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, (c) provide security for remediation and mitigation liabilities, and (d) provide security in respect of conditional use permit sales tax obligations. As of December 31, 2015 and 2014 , $600 million and $245 million , respectively, of letters of credit had been issued under these facilities. As of December 31, 2015 and 2014 , certain renewable projects collectively have letters of credit outstanding of $65 million and $63 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): 2015: Credit facilities $ 1,200 Less: Short-term debt (20 ) Tax-exempt bond support and letters of credit (160 ) Net credit facilities $ 1,020 2014: Credit facilities $ 1,200 Less: Short-term debt (20 ) Letters of credit and tax-exempt bond support (398 ) Net credit facilities $ 782 PacifiCorp has a $600 million unsecured credit facility expiring in June 2017 and a $600 million unsecured credit facility expiring in March 2018. 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, 2015 and 2014 , the weighted average interest rate on commercial paper borrowings outstanding was 0.65% and 0.43% , 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, 2015 , PacifiCorp was in compliance with the covenants of its credit facilities. As of December 31, 2015 and 2014 , PacifiCorp had $310 million and $451 million , respectively, of fully available letters of credit issued under committed arrangements, of which $10 million and $270 million as of December 31, 2015 and 2014 were issued under the credit facilities. These letters of credit support PacifiCorp's variable-rate tax-exempt bond obligations and expire through March 2017. As of December 31, 2015 , PacifiCorp had approximately $15 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, 2015 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 2016 and has a variable interest rate based on LIBOR plus a spread. As of December 31, 2014 , the weighted average interest rate on commercial paper borrowings outstanding was 0.35% . 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, 2015 , 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 June 30, 2016 . The following table summarizes MidAmerican Energy's availability under its two unsecured revolving credit facilities as of December 31 (in millions): 2015 2014 Credit facilities $ 605 $ 605 Less: Short-term debt outstanding — (50 ) Variable-rate tax-exempt bond support (195 ) (195 ) Net credit facilities $ 410 $ 360
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 7 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 2016 and has a variable interest rate based on LIBOR plus a spread. As of December 31, 2015 and 2014 , there were no borrowings outstanding under this credit facility. As of December 31, 2015 , 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 , 2015 and 2014 , 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 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. As of December 31 , 2015 and 2014 , Sierra Pacific had no borrowings outstanding under the credit facility. 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, 2015
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 2015 2014 1.10% Senior Notes, due 2017 $ 400 $ 399 $ 399 5.75% Senior Notes, due 2018 650 648 648 2.00% Senior Notes, due 2018 350 348 348 2.40% Senior Notes, due 2020 350 348 348 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 1,688 5.95% Senior Bonds, due 2037 550 547 547 6.50% Senior Bonds, due 2037 1,000 987 986 5.15% Senior Notes, due 2043 750 739 738 4.50% Senior Notes, due 2045 750 737 737 Total BHE Senior Debt $ 7,875 $ 7,814 $ 7,810 Reflected as: Current liabilities $ — $ — Noncurrent liabilities 7,814 7,810 Total BHE Senior Debt $ 7,814 $ 7,810 Junior Subordinated Debentures BHE junior subordinated debentures consists of the following as of December 31 (in millions): Par Value 2015 2014 Junior subordinated debentures, due 2043 $ 1,444 $ 1,444 $ 2,294 Junior subordinated debentures, due 2044 1,500 1,500 1,500 Total BHE junior subordinated debentures - noncurrent $ 2,944 $ 2,944 $ 3,794 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, 2015 and 2014 , the interest rate was 3.0% . Interest expense to Berkshire Hathaway for the years ended December 31, 2015 , 2014 and 2013 was $104 million , $78 million and $3 million , respectively. In February 2016, BHE provided notice of redemption for $500 million of the junior subordinated debentures due 2043 at par value to occur in March 2016.

Subsidiary Debt (Notes)

Subsidiary Debt (Notes)	12 Months Ended
	Dec. 31, 2015
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, 2015 , 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 2015 2014 PacifiCorp $ 7,204 $ 7,159 $ 7,055 MidAmerican Funding 4,627 4,560 4,323 NV Energy 4,840 4,860 5,118 Northern Powergrid 2,735 2,772 2,317 BHE Pipeline Group 1,045 1,040 1,358 BHE Transmission 3,469 3,467 3,743 BHE Renewables 3,394 3,356 2,934 Total subsidiary debt $ 27,314 $ 27,214 $ 26,848 Reflected as: Current liabilities $ 1,148 $ 1,232 Noncurrent liabilities 26,066 25,616 Total subsidiary debt $ 27,214 $ 26,848 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 2015 2014 First mortgage bonds: 5.50% to 8.635%, due through 2019 $ 855 $ 853 $ 859 2.95% to 8.53%, due 2021 to 2025 2,149 2,137 1,888 6.71% due 2026 100 100 100 5.25% to 7.70%, due 2031 to 2035 800 794 793 5.75% to 6.35%, due 2036 to 2039 2,500 2,480 2,479 4.10% due 2042 300 297 297 Variable-rate series, tax-exempt bond obligations (2015-0.01% to 0.22%; 2014-0.02% to 0.22%): Due 2018 to 2025 (1) 107 107 223 Due 2016 to 2024 (1)(2) 198 196 219 Due 2016 to 2025 (2) 59 59 36 Due 2017 to 2018 91 91 91 Capital lease obligations - 8.75% to 15.678%, due through 2035 45 45 70 Total PacifiCorp $ 7,204 $ 7,159 $ 7,055 (1) Supported by $310 million and $451 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2015 and 2014 , 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 $25 billion of PacifiCorp's eligible property (based on original cost) was subject to the lien of the mortgage as of December 31, 2015 . 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 2015 2014 MidAmerican Funding: 6.927% Senior Bonds, due 2029 $ 325 $ 289 $ 289 MidAmerican Energy: Tax-exempt bond obligations - Variable-rate series (2015-0.03%, 2014-0.07%), due 2016-2038 195 194 194 First Mortgage Bonds: 2.40%, due 2019 500 499 498 3.70%, due 2023 250 248 248 3.50%, due 2024 500 502 296 4.80%, due 2043 350 345 345 4.40%, due 2044 400 394 394 4.25%, due 2046 450 444 — Notes: 5.95% Series, due 2017 250 250 250 5.3% Series, due 2018 350 349 349 6.75% Series, due 2031 400 395 395 5.75% Series, due 2035 300 298 298 5.8% Series, due 2036 350 347 347 Turbine purchase obligation, 1.43% due 2015 (1) — — 420 Transmission upgrade obligation, 4.45% due through 2035 5 4 — Capital lease obligations - 4.16%, due through 2020 2 2 — Total MidAmerican Energy 4,302 4,271 4,034 Total MidAmerican Funding $ 4,627 $ 4,560 $ 4,323 (1) In conjunction with the construction of wind-powered generating facilities in 2012, MidAmerican Energy accrued as property, plant and equipment amounts for turbine purchases it was not contractually obligated to pay until December 2015. The amount ultimately payable was discounted and recognized upon delivery of the equipment as long-term debt. The discount was amortized as interest expense over the period until payment was due using the effective interest method. 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, 2015 , MidAmerican Energy's eligible property subject to the lien of the mortgage totaled approximately $13 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 2015 2014 NV Energy - 6.250% Senior Notes, due 2020 $ 315 $ 373 $ 384 Nevada Power: General and Refunding Mortgage Securities: 5.875% Series L, due 2015 — — 250 5.950% Series M, due 2016 210 210 209 6.500% Series O, due 2018 324 323 322 6.500% Series S, due 2018 499 498 497 7.125% Series V, due 2019 500 499 499 6.650% Series N, due 2036 367 356 356 6.750% Series R, due 2037 349 345 345 5.375% Series X, due 2040 250 247 247 5.450% Series Y, due 2041 250 235 234 Variable-rate series (2015-0.672% to 1.055%, 2014-0.455% to 0.464%): 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 497 497 510 Total Nevada Power 3,322 3,285 3,544 Sierra Pacific: General and Refunding Mortgage Securities: 6.000% Series M, due 2016 450 450 451 3.375% Series T, due 2023 250 248 247 6.750% Series P, due 2037 252 255 255 Variable-rate series (2015-0.733% to 1.054%, 2014-0.464% to 0.466%): Pollution Control Revenue Bonds Series 2006A, due 2031 58 58 58 Pollution Control Revenue Bonds Series 2006B, due 2036 75 74 74 Pollution Control Revenue Bonds Series 2006C, due 2036 81 80 79 Capital and financial lease obligations - 2.700% to 8.548%, due through 2054 37 37 26 Total Sierra Pacific 1,203 1,202 1,190 Total NV Energy $ 4,840 $ 4,860 $ 5,118 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, 2015 , approximately $8.7 billion of Nevada Power's and $3.7 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) 2015 2014 8.875% Bonds, due 2020 $ 147 $ 162 $ 172 9.25% Bonds, due 2020 295 315 338 3.901% to 4.586% European Investment Bank loans, due 2018 to 2022 398 398 420 7.25% Bonds, due 2022 295 306 324 2.50% Bonds due 2025 221 217 — 2.564% European Investment Bank loans, due 2027 369 368 — 7.25% Bonds, due 2028 273 280 297 4.375% Bonds, due 2032 221 217 229 5.125% Bonds, due 2035 295 291 307 5.125% Bonds, due 2035 221 218 230 Total Northern Powergrid $ 2,735 $ 2,772 $ 2,317 (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 2015 2014 Northern Natural Gas: 5.125% Senior Notes, due 2015 $ — $ — $ 100 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 250 248 247 Total Northern Natural Gas 800 795 894 Kern River: 6.676% Senior Notes, due 2016 — — 165 4.893% Senior Notes, due 2018 245 245 299 Total Kern River 245 245 464 Total BHE Pipeline Group $ 1,045 $ 1,040 $ 1,358 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 $33 million and $55 million as of December 31, 2015 and 2014 , 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) 2015 2014 AltaLink Investments, L.P.: Series 09-1 Senior Bonds, 5.207%, due 2016 $ 108 $ 112 $ 136 Series 12-1 Senior Bonds, 3.674%, due 2019 145 151 180 Series 13-1 Senior Bonds, 3.265%, due 2020 145 149 176 Series 15-1 Senior Bonds, 2.244%, due 2022 145 144 — Total AltaLink Investments, L.P. 543 556 492 AltaLink Holdings, L.P. Senior debentures, 10.5%, due 2015 — — 78 ALP: Series 2008-1 Notes, 5.243%, due 2018 145 145 171 Series 2013-2 Notes, 3.621%, due 2020 90 90 108 Series 2012-2 Notes, 2.978%, due 2022 199 198 236 Series 2013-4 Notes, 3.668%, due 2023 361 360 429 Series 2014-1 Notes, 3.399%, due 2024 253 252 300 Series 2006-1 Notes, 5.249%, due 2036 108 108 128 Series 2010-1 Notes, 5.381%, due 2040 90 90 108 Series 2010-2 Notes, 4.872%, due 2040 108 108 128 Series 2011-1 Notes, 4.462%, due 2041 199 198 236 Series 2012-1 Notes, 3.99%, due 2042 379 374 451 Series 2013-3 Notes, 4.922%, due 2043 253 252 300 Series 2014-3 Notes, 4.054%, due 2044 213 212 253 Series 2015-1 Notes, 4.090%, due 2045 253 251 — Series 2013-1 Notes, 4.446%, due 2053 181 180 214 Series 2014-2 Notes, 4.274%, due 2064 94 93 111 Total AltaLink, L.P. 2,926 2,911 3,173 Total BHE Transmission $ 3,469 $ 3,467 $ 3,743 (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 2015 2014 Fixed-rate (1) : CE Generation Bonds, 7.416%, due 2018 $ 96 $ 97 $ 125 Salton Sea Funding Corporation Bonds, 7.475%, due 2018 50 51 71 Cordova Funding Corporation Bonds, 8.48% to 9.07%, due 2019 112 113 125 Bishop Hill Holdings Senior Notes, 5.125%, due 2032 104 102 107 Solar Star Funding Senior Notes, 3.950%, due 2035 325 321 — Solar Star Funding Senior Notes, 5.375%, due 2035 1,000 988 987 Topaz Solar Farms Senior Notes, 5.750%, due 2039 826 815 838 Topaz Solar Farms Senior Notes, 4.875%, due 2039 242 239 247 Other 25 25 27 Variable-rate (1) : Pinyon Pines I and II Term Loans, due 2019 (2) 380 378 398 Wailuku Special Purpose Revenue Bonds, 0.12%, due 2021 8 8 9 TX Jumbo Road Term Loan, 3.626%, due 2025 226 219 — Total BHE Renewables $ 3,394 $ 3,356 $ 2,934 (1) Amortizes quarterly or semiannually. (2) The term loans have variable interest rates based on LIBOR plus a spread that varies during the term of the agreement. The weighted average variable interest rate as of December 31, 2015 and 2014 was 2.23% and 1.88% , respectively. The Company has entered into interest rate swaps that fix the interest rate on 75% of the outstanding debt. The weighted average fixed interest rate for the 75% portion is fixed at 3.55% as of December 31, 2015 and 2014 . Annual Repayments of Long-Term Debt The annual repayments of BHE and subsidiary debt for the years beginning January 1, 2016 and thereafter, excluding fair value adjustments and unamortized premiums, discounts and debt issuance costs, are as follows (in millions): 2021 and 2016 2017 2018 2019 2020 Thereafter Total BHE senior notes $ — $ 400 $ 1,000 $ — $ 350 $ 6,125 $ 7,875 BHE junior subordinated debentures — — — — — 2,944 2,944 PacifiCorp 81 57 589 353 41 6,083 7,204 MidAmerican Funding 34 254 350 500 1 3,488 4,627 NV Energy 676 16 840 519 336 2,453 4,840 Northern Powergrid — — 59 59 500 2,117 2,735 BHE Pipeline Group 54 62 329 — — 600 1,045 BHE Transmission 110 — 145 145 235 2,834 3,469 BHE Renewables 193 196 208 494 126 2,177 3,394 Totals $ 1,148 $ 985 $ 3,520 $ 2,070 $ 1,589 $ 28,821 $ 38,133
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): 2015 2014 Average Average Principal Carrying Interest Carrying Interest Amount Value Rate Value Rate First mortgage bonds: 5.50% to 8.635%, due through 2019 $ 855 $ 853 5.61 % $ 859 5.63 % 2.95% to 8.53%, due 2021 to 2025 2,149 2,137 4.01 1,888 4.09 6.71% due 2026 100 100 6.71 100 6.71 5.25% to 7.70%, due 2031 to 2035 800 794 6.33 793 6.33 5.75% to 6.35%, due 2036 to 2039 2,500 2,480 6.06 2,479 6.06 4.10% due 2042 300 297 4.10 297 4.10 Tax-exempt bond obligations: Variable rates, due 2018 to 2025 (1) 107 107 0.01 223 0.03 Variable rates, due 2016 to 2024 (1)(2) 198 196 0.02 219 0.02 Variable rates, due 2016 to 2025 (2) 59 59 0.21 36 0.22 Variable rates, due 2017 to 2018 91 91 0.22 91 0.22 Total long-term debt 7,159 7,114 6,985 Capital lease obligations: 8.75% to 14.61%, due through 2035 32 32 11.25 34 11.33 Total long-term debt and capital lease obligations $ 7,191 $ 7,146 $ 7,019 Reflected as: 2015 2014 Current portion of long-term debt and capital lease obligations $ 68 $ 134 Long-term debt and capital lease obligations 7,078 6,885 Total long-term debt and capital lease obligations $ 7,146 $ 7,019 1) Supported by $310 million and $451 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2015 and 2014 , 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. In June 2015, PacifiCorp issued $250 million of its 3.35% First Mortgage Bonds due July 2025. The net proceeds were used to fund capital expenditures and for general corporate purposes, including retirement of short-term debt. 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 $25 billion of PacifiCorp's eligible property (based on original cost) was subject to the lien of the mortgage as of December 31, 2015 . PacifiCorp has entered into long-term agreements that qualify as capital leases and expire at various dates through March 2035 for transportation services, power purchase agreements 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 $32 million and $34 million as of December 31, 2015 and 2014 , respectively, were included in property, plant and equipment, net in the Consolidated Balance Sheets. As of December 31, 2015 , the annual principal maturities of long-term debt and total capital lease obligations for 2016 and thereafter are as follows (in millions): Long-term Capital Lease Debt Obligations Total 2016 $ 66 $ 5 $ 71 2017 52 10 62 2018 586 5 591 2019 350 5 355 2020 38 4 42 Thereafter 6,067 27 6,094 Total 7,159 56 7,215 Unamortized discount and debt issuance costs (45 ) — (45 ) Amounts representing interest — (24 ) (24 ) Total $ 7,114 $ 32 $ 7,146
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 2015 2014 First mortgage bonds: 2.40%, due 2019 $ 500 $ 499 $ 498 3.70%, due 2023 250 248 248 3.50%, due 2024 500 502 296 4.80%, due 2043 350 345 345 4.40%, due 2044 400 394 394 4.25%, due 2046 450 444 — Notes: 5.95% Series, due 2017 250 250 250 5.3% Series, due 2018 350 349 349 6.75% Series, due 2031 400 395 395 5.75% Series, due 2035 300 298 298 5.8% Series, due 2036 350 347 347 Turbine purchase obligation, 1.43%, due 2015 (1) — — 420 Transmission upgrade obligation, 4.449%, due through 2035 5 4 — Variable-rate tax-exempt bond obligation series: (weighted average interest rate- 2015-0.03%, 2014-0.07%) Due 2016 34 33 33 Due 2017 4 4 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 2038 45 45 45 Capital lease obligations - 4.16%, due through 2020 2 2 — Total $ 4,302 $ 4,271 $ 4,034 (1) In conjunction with the construction of wind-powered generating facilities in 2012, MidAmerican Energy accrued as gross property, plant and equipment amounts for turbine purchases it is not contractually obligated to pay until December 2015. The amount ultimately payable was discounted and recognized upon delivery of the equipment as long-term debt. The discount was amortized as interest expense over the period until payment was due using the effective interest method. The annual repayments of MidAmerican Energy's long-term debt for the years beginning January 1, 2016 , and thereafter, excluding unamortized premiums, discounts and debt issuance costs, are as follows (in millions): 2016 $ 34 2017 254 2018 351 2019 500 2020 1 2021 and thereafter 3,162 MidAmerican Energy issued $650 million of first mortgage bonds in October 2015 pursuant to its indenture dated September 9, 2013, as supplemented and amended. The net proceeds were used for the payment of the $426 million turbine purchase obligation due December 2015 and for general corporate purposes. 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, 2015 , MidAmerican Energy's eligible property subject to the lien of the mortgage totaled approximately $13 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 below, 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, 2015 and 2014 . MidAmerican Energy maintains revolving credit facility agreements to provide liquidity for holders of these issues. As of December 31, 2015 , 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, 2015 , MidAmerican Energy's common equity ratio was 52% 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 $1.6 billion as of December 31, 2015 , 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 8 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, 2015 and 2014 . 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 8 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, 2015 . As of December 31, 2015 , 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 2015 2014 General and Refunding Mortgage Securities: 5.875% Series L, due 2015 $ — $ — $ 250 5.950% Series M, due 2016 210 210 209 6.500% Series O, due 2018 324 323 322 6.500% Series S, due 2018 499 498 497 7.125% Series V, due 2019 500 499 499 6.650% Series N, due 2036 367 356 356 6.750% Series R, due 2037 349 345 345 5.375% Series X, due 2040 250 247 247 5.450% Series Y, due 2041 250 235 234 Variable-rate series (2015-0.672% to 1.055%, 2014-0.455% to 0.464%): 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 497 497 510 Total long-term debt and financial and capital leases $ 3,322 $ 3,285 $ 3,544 Reflected as: Current portion of long-term debt and financial and capital lease obligations $ 225 $ 264 Long-term debt and financial and capital lease obligations 3,060 3,280 Total long-term debt and financial and capital leases $ 3,285 $ 3,544 The consummation of the BHE Merger triggered mandatory redemption requirements under financing agreements of Nevada Power . As a result, Nevada Power offered to purchase $3.0 billion of debt at 101% of par. Debt with a par value totaling $5 million was tendered in January 2014 and paid with cash on hand. The tender offer expired in January 2014. 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, 2016 and thereafter, are as follows (in millions): Long-term Capital and Financial Debt Lease Obligations Total 2016 $ 210 $ 73 $ 283 2017 — 75 75 2018 823 74 897 2019 500 75 575 2020 — 74 74 Thereafter 1,292 908 2,200 Total 2,825 1,279 4,104 Unamortized premium, discount and debt issuance cost (37 ) — (37 ) Executory costs — (129 ) (129 ) Amounts representing interest — (653 ) (653 ) Total $ 2,788 $ 497 $ 3,285 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, 2015 , approximately $8.7 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 $27 million and $28 million were included in property, plant and equipment, net as of December 31 , 2015 and 2014 , 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 and $8 million were included in property, plant and equipment, net as of December 31 , 2015 and 2014 , respectively. • 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 firm operation occurred through 1993. The terms of the leases are for 30 years and expire between the years 2022-2023. Capital assets of $40 million and $44 million were included in property, plant and equipment, net as of December 31 , 2015 and 2014 , 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 , 2015 and 2014 . • 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 $410 million and $418 million were included in property, plant and equipment, net as of December 31 , 2015 and 2014 , 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 2015 2014 General and Refunding Mortgage Securities: 6.000% Series M, due 2016 $ 450 $ 450 $ 451 3.375% Series T, due 2023 250 248 247 6.750% Series P, due 2037 252 255 255 Variable-rate series (2015-0.733% to 1.054%, 2014-0.464% to 0.466%): Pollution Control Revenue Bonds Series 2006A, due 2031 58 58 58 Pollution Control Revenue Bonds Series 2006B, due 2036 75 74 74 Pollution Control Revenue Bonds Series 2006C, due 2036 81 80 79 Capital and financial lease obligations - 2.700% to 8.548%, due through 2054 37 37 26 Total long-term debt and financial and capital leases $ 1,203 $ 1,202 $ 1,190 Reflected as: Current portion of long-term debt and financial and capital lease obligations $ 453 $ 1 Long-term debt and financial and capital lease obligations 749 1,189 Total long-term debt and financial and capital leases $ 1,202 $ 1,190 The consummation of the BHE Merger triggered mandatory redemption requirements under financing agreements of Sierra Pacific . As a result, Sierra Pacific offered to purchase $702 million of debt at 101% of par. The tender offer expired in January 2014 with no amounts tendered. 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, 2016 and thereafter, are as follows (in millions): Long-term Capital and Financial Debt Lease Obligations Total 2016 $ 450 $ 6 $ 456 2017 — 4 4 2018 — 4 4 2019 — 4 4 2020 — 3 3 Thereafter 716 53 769 Total 1,166 74 1,240 Unamortized premium, discount and debt issuance cost (1 ) — (1 ) Amounts representing interest — (37 ) (37 ) Total $ 1,165 $ 37 $ 1,202 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, 2015 , approximately $3.7 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 , 2015 and 2014 . • 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 $22 million were included in property, plant and equipment, net as of December 31 , 2015 and 2014 . • In 2015, Sierra Pacific entered into a 20 -year capital lease for the Fort Churchill Solar Array. Capital assets of $12 million were included in property, plant and equipment, net as of December 31 , 2015 .

Risk Management and Hedging Act

Risk Management and Hedging Activities (Notes)	12 Months Ended
	Dec. 31, 2015
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 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, 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 ) As of December 31, 2014 Not designated as hedging contracts: Commodity assets (1) $ 47 $ 66 $ 21 $ 1 $ 135 Commodity liabilities (1) (11 ) — (146 ) (134 ) (291 ) Interest rate assets 4 — — — 4 Interest rate liabilities — — (2 ) (4 ) (6 ) Total 40 66 (127 ) (137 ) (158 ) Designated as hedging contracts: Commodity assets 1 — 5 2 8 Commodity liabilities — — (27 ) (17 ) (44 ) Interest rate assets — 1 — — 1 Interest rate liabilities — — (4 ) — (4 ) Total 1 1 (26 ) (15 ) (39 ) Total derivatives 41 67 (153 ) (152 ) (197 ) Cash collateral receivable — — 56 19 75 Total derivatives - net basis $ 41 $ 67 $ (97 ) $ (133 ) $ (122 ) (1) The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31, 2015 and 2014 , a net regulatory asset of $250 million and $223 million , respectively, was recorded related to the net derivative liability of $186 million and $156 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 2015 2014 2013 Beginning balance $ 223 $ 182 $ 235 NV Energy Transaction — — 47 Changes in fair value recognized in net regulatory assets 128 96 29 Net gains (losses) reclassified to operating revenue 1 (32 ) 8 Net losses reclassified to cost of sales (102 ) (23 ) (137 ) Ending balance $ 250 $ 223 $ 182 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 2015 2014 2013 Beginning balance $ 32 $ 12 $ 32 Changes in fair value recognized in OCI 52 (6 ) (9 ) Net gains reclassified to operating revenue 9 — — Net (losses) gains reclassified to cost of sales (47 ) 26 (11 ) Ending balance $ 46 $ 32 $ 12 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, 2015 , 2014 and 2013 , hedge ineffectiveness was insignificant . As of December 31, 2015 , the Company had cash flow hedges with expiration dates extending through September 2025 and $36 million of pre-tax unrealized losses are forecasted to be reclassified from AOCI into earnings over the next twelve months as contracts settle. Derivative Contract Volumes The following table summarizes the net notional amounts of outstanding derivative contracts with fixed price terms that comprise the mark-to-market values as of December 31 (in millions): Unit of Measure 2015 2014 Electricity purchases Megawatt hours 10 6 Natural gas purchases Decatherms 317 308 Fuel purchases Gallons 11 2 Interest rate swaps US$ 653 443 Mortgage sale commitments, net US$ (312 ) (264 ) 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, 2015 , 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 $288 million and $243 million as of December 31, 2015 and 2014 , respectively, for which the Company had posted collateral of $75 million and $28 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, 2015 and 2014 , the Company would have been required to post $198 million and $182 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, 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, 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, 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 ) As of December 31, 2014 Not designated as hedging contracts (1) : Commodity assets $ 28 $ — $ 1 $ — $ 29 Commodity liabilities (10 ) — (55 ) (49 ) (114 ) Total 18 — (54 ) (49 ) (85 ) Total derivatives 18 — (54 ) (49 ) (85 ) Cash collateral receivable — — 14 14 28 Total derivatives - net basis $ 18 $ — $ (40 ) $ (35 ) $ (57 ) (1) PacifiCorp's commodity derivatives are generally included in rates and as of December 31, 2015 and 2014 , a regulatory asset of $133 million and $85 million , respectively, was recorded related to the net derivative liability of $136 million and $85 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): 2015 2014 Beginning balance $ 85 $ 55 Changes in fair value recognized in regulatory assets 82 45 Net gains (losses) reclassified to operating revenue 40 (4 ) Net losses reclassified to energy costs (74 ) (11 ) Ending balance $ 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 2015 2014 Electricity purchases (sales) Megawatt hours 1 (1 ) Natural gas purchases Decatherms 111 113 Fuel oil purchases Gallons 11 3 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, 2015 , 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 $142 million and $113 million as of December 31, 2015 and 2014 , respectively, for which PacifiCorp had posted collateral of $75 million and $28 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, 2015 and 2014 , PacifiCorp would have been required to post $64 million and $75 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. MidAmerican Energy has also provided nonregulated retail electricity and natural gas services in competitive markets. 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 13 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 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): Current Other Current Other Assets Assets Liabilities Liabilities - Other - Other - Other - Other Total 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 ) As of December 31, 2014 Not designated as hedging contracts (1) : Commodity assets $ 14 $ 3 $ 19 $ 1 $ 37 Commodity liabilities — — (69 ) (4 ) (73 ) Total 14 3 (50 ) (3 ) (36 ) Designated as hedging contracts: Commodity assets — — 4 2 6 Commodity liabilities — — (27 ) (17 ) (44 ) Total — — (23 ) (15 ) (38 ) Total derivatives 14 3 (73 ) (18 ) (74 ) Cash collateral receivable — — 42 5 47 Total derivatives - net basis $ 14 $ 3 $ (31 ) $ (13 ) $ (27 ) (1) MidAmerican Energy's commodity derivatives not designated as hedging contracts are generally included in regulated rates. Accordingly, as of December 31, 2015 and 2014 , a net regulatory asset of $20 million and $38 million , respectively, was recorded related to the net derivative liability of $26 million and $36 million , respectively. Not Designated as Hedging Contracts The following table reconciles the beginning and ending balances of MidAmerican Energy'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): 2015 2014 2013 Beginning balance $ 38 $ 10 $ 45 Changes in fair value recognized in net regulatory assets 40 61 5 Net losses reclassified to operating revenue (42 ) (28 ) (1 ) Net losses reclassified to cost of fuel, energy and capacity (1 ) (1 ) (1 ) Net losses reclassified to cost of gas sold (15 ) (4 ) (38 ) Ending balance $ 20 $ 38 $ 10 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): 2015 2014 2013 Nonregulated operating revenue $ 15 $ 6 $ — Regulated cost of fuel, energy and capacity 2 — — Nonregulated cost of sales (21 ) 9 (2 ) Total $ (4 ) $ 15 $ (2 ) Designated as Hedging Contracts MidAmerican Energy uses derivative contracts accounted for as cash flow hedges to hedge electricity and natural gas commodity prices for delivery to nonregulated customers. 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): 2015 2014 2013 Beginning balance $ 34 $ 11 $ 32 Changes in fair value recognized in OCI 58 (3 ) (11 ) Net (losses) gains reclassified to nonregulated cost of sales (47 ) 26 (10 ) Ending balance $ 45 $ 34 $ 11 Realized gains and losses on hedges and hedge ineffectiveness are recognized in income as nonregulated operating revenue or nonregulated cost of sales depending upon the nature of the item being hedged. For the years ended December 31, 2015 , 2014 and 2013 , hedge ineffectiveness was a pre-tax gain of $1 million , a pre-tax loss of $2 million and $- million, respectively. As of December 31, 2015 , MidAmerican Energy had cash flow hedges with expiration dates extending through December 2020 , and $32 million of pre-tax net 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 2015 2014 Electricity purchases Megawatt hours 15 14 Natural gas purchases Decatherms 17 19 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, 2015 , 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 $66 million and $52 million as of December 31, 2015 and 2014 , 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, 2015 and 2014 , MidAmerican Energy would have been required to post $55 million and $36 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 Funding, LLC and Subsidiaries [Domain]
Derivative [Line Items]
Risk Management and Hedging Activities [Text Block]	Risk Management and Hedging Activities Refer to Note 12 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, 2015 Commodity liabilities (1) $ (8 ) $ (14 ) $ (22 ) As of December 31, 2014 Commodity liabilities (1) $ (9 ) $ (21 ) $ (30 ) (1) Nevada Power 's commodity derivatives not designated as hedging contracts are included in regulated rates and as of December 31 , 2015 and 2014 , a regulatory asset of $22 million and $30 million , respectively, was recorded related to the derivative liability of $22 million and $30 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 2015 2014 Electricity sales Megawatt hours (2 ) (3 ) Natural gas purchases Decatherms 126 115 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, 2015 , 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 $3 million , 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, 2015
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, 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 ) As of December 31, 2014 Assets: Commodity derivatives $ 1 $ 48 $ 94 $ (40 ) $ 103 Interest rate derivatives — 5 — — 5 Mortgage loans held for sale — 279 — — 279 Money market mutual funds (2) 320 — — — 320 Debt securities: United States government obligations 136 — — — 136 International government obligations — 1 — — 1 Corporate obligations — 39 — — 39 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Auction rate securities — — 45 — 45 Equity securities: United States companies 238 — — — 238 International companies 886 — — — 886 Investment funds 137 — — — 137 $ 1,718 $ 376 $ 139 $ (40 ) $ 2,193 Liabilities: Commodity derivatives $ (18 ) $ (274 ) $ (43 ) $ 115 $ (220 ) Interest rate derivatives — (10 ) — — (10 ) $ (18 ) $ (284 ) $ (43 ) $ 115 $ (230 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $103 million and $75 million as of December 31, 2015 and 2014 , 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, where there is no current liquid market, is 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 2015 2014 2013 2015 2014 2013 2015 2014 2013 Beginning balance $ 51 $ 60 $ 32 $ — $ — $ — $ 45 $ 44 $ 41 Changes included in earnings 19 19 34 87 — — — — — Changes in fair value recognized in OCI (7 ) — (2 ) — — — (1 ) 1 3 Changes in fair value recognized in net regulatory assets (19 ) 5 1 — — — — — — Purchases 1 1 4 — — — — — — Settlements 2 1 (9 ) (86 ) — — — — — Transfers from Level 2 — (35 ) — 3 — — — — — Ending balance $ 47 $ 51 $ 60 $ 4 $ — $ — $ 44 $ 45 $ 44 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): 2015 2014 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 37,972 $ 41,785 $ 38,649 $ 43,863
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, 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 ) As of December 31, 2014 Assets: Commodity derivatives $ — $ 25 $ 4 $ (11 ) $ 18 Money market mutual funds (2) 30 — — — 30 $ 30 $ 25 $ 4 $ (11 ) $ 48 Liabilities - Commodity derivatives $ — $ (114 ) $ — $ 39 $ (75 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $75 million and $28 million as of December 31, 2015 and 2014 , respectively. (2) Amounts are included in cash and cash equivalents, other current assets and other assets on the Consolidated Balance Sheets. Money market mutual funds are accounted for as available-for-sale securities and the fair value 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. 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. 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): 2015 2014 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 7,114 $ 8,210 $ 6,985 $ 8,358
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, 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 ) As of December 31, 2014: Assets: Commodity derivatives $ 1 $ 18 $ 24 $ (26 ) $ 17 Money market mutual funds (2) 1 — — — 1 Debt securities: United States government obligations 136 — — — 136 International government obligations — 1 — — 1 Corporate obligations — 39 — — 39 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Auction rate securities — — 26 — 26 Equity securities: United States companies 238 — — — 238 International companies 5 — — — 5 $ 381 $ 62 $ 50 $ (26 ) $ 467 Liabilities - commodity derivatives $ (18 ) $ (87 ) $ (12 ) $ 73 $ (44 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $28 million and $47 million as of December 31, 2015 and 2014 , 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 12 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 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 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 2015 2014 2013 2015 2014 2013 Beginning balance $ 12 $ (3 ) $ — $ 26 $ 23 $ 21 Changes included in earnings (1) 11 12 3 — — — Changes in fair value recognized in OCI (7 ) — (2 ) — 3 2 Changes in fair value recognized in net regulatory assets (25 ) 6 — — — — Purchases 1 1 — — — — Settlements 2 (4 ) (4 ) — — — Ending balance $ (6 ) $ 12 $ (3 ) $ 26 $ 26 $ 23 (1) Changes included in earnings are reported as nonregulated operating revenue on the Statements of Operations. Net unrealized (losses) gains included in earnings for the years ended December 31, 2015 , 2014 and 2013 , related to commodity derivatives held at December 31, 2015 , 2014 and 2013 , totaled $8 million , $16 million and $(5) 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): 2015 2014 Carrying Value Fair Value Carrying Value Fair Value Long-term debt $ 4,271 $ 4,636 $ 4,056 $ 4,581
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 13 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): 2015 2014 Carrying Value Fair Value Carrying Value Fair Value Long-term debt $ 4,597 $ 5,051 $ 4,381 $ 5,012
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, 2015 Assets - investment funds $ 5 $ — $ — $ 5 Liabilities - commodity derivatives $ — $ — $ (22 ) $ (22 ) As of December 31, 2014 Assets - investment funds $ 20 $ — $ — $ 20 Liabilities - commodity derivatives $ — $ — $ (30 ) $ (30 ) 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. Interest rate swaps are valued using a financial model which utilizes observable inputs for similar instruments based primarily on market price curves. 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, 2015 , 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): 2015 2014 Beginning balance $ (30 ) $ (47 ) Changes in fair value recognized in regulatory assets — 9 Purchases — — Settlements 8 8 Ending balance $ (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): 2015 2014 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 2,788 $ 3,240 $ 3,034 $ 3,712
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, investments held in Rabbi trusts, 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, principally related to derivative contracts, 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. 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): 2015 2014 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 1,165 $ 1,248 $ 1,164 $ 1,301

Other, Net (Notes)

Other, Net (Notes)	12 Months Ended
	Dec. 31, 2015
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): 2015 2014 2013 Corporate-owned life insurance income $ 4 $ 8 $ 15 Gains on sales of assets and other investments — — 1 Other, net 1 2 — Total $ 5 $ 10 $ 16
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): 2015 2014 2013 Corporate-owned life insurance income $ 4 $ 8 $ 15 Gains on sales of assets and other investments 13 — 1 Leverage leases 1 5 2 Other, net 1 5 4 Total $ 19 $ 18 $ 22 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, 2015
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): 2015 2014 2013 Current: Federal $ (929 ) $ (1,872 ) $ (985 ) State 29 (3 ) (2 ) Foreign 84 129 121 (816 ) (1,746 ) (866 ) Deferred: Federal 1,310 2,296 1,306 State (53 ) 37 (247 ) Foreign 17 11 (59 ) 1,274 2,344 1,000 Investment tax credits (8 ) (9 ) (4 ) Total $ 450 $ 589 $ 130 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: 2015 2014 2013 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (11 ) (10 ) (14 ) State income tax, net of federal income tax benefit (1 ) 1 (9 ) Income tax effect of foreign income (7 ) (3 ) (6 ) Equity income (loss) 2 2 (1 ) Other, net (2 ) (2 ) 2 Effective income tax rate 16 % 23 % 7 % 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. State income tax benefits decreased for 2014 compared to 2013 primarily due to one-time deferred income tax benefits recognized from a reduction in the apportioned state tax rate of $161 million , in part, as a result of BHE 's acquisition of NV Energy. Income tax effect of foreign income includes, among other items, deferred income tax benefits of $39 million in 2015 and $54 million in 2013 related to the enactment of reductions in the United Kingdom corporate income tax rate. In November 2015 the corporate tax rate was reduced from 20% to 19% effective April 1, 2017, with a further reduction to 18% effective April 1, 2020. In July 2013 the corporate income tax rate was reduced from 23% to 21% effective April 1, 2014, with a further reduction to 20% effective April 1, 2015. Berkshire Hathaway includes the Company in its United States federal income tax return. As of December 31, 2015 and 2014 , the Company had current income taxes receivable from Berkshire Hathaway of $286 million and $1.1 billion , respectively. The net deferred income tax liability consists of the following as of December 31 (in millions): 2015 2014 Deferred income tax assets: Federal, state and foreign carryforwards $ 865 $ 781 Regulatory liabilities 834 812 AROs 317 249 Employee benefits 190 187 Derivative contracts 83 62 Other 815 781 Total deferred income tax assets 3,104 2,872 Valuation allowances (35 ) (23 ) Total deferred income tax assets, net 3,069 2,849 Deferred income tax liabilities: Property-related items (13,157 ) (11,989 ) Regulatory assets (1,446 ) (1,374 ) Investments (852 ) (699 ) Other (299 ) (301 ) Total deferred income tax liabilities (15,754 ) (14,363 ) Net deferred income tax liability $ (12,685 ) $ (11,514 ) The following table provides the Company's net operating loss and tax credit carryforwards and expiration dates as of December 31, 2015 (in millions): Federal State Net operating loss carryforwards (1) $ 185 $ 10,084 Deferred income taxes on net operating loss carryforwards $ 69 $ 589 Expiration dates 2023-2026 2016-2035 Foreign and other tax credits (2) $ 176 $ 31 Expiration dates 2023- indefinite 2016- 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 net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2022. (2) Includes $102 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, 2015 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) examinations of PacifiCorp's state returns, which have been closed through March 31, 2006 (except for the December 1995 and 1997 tax years in Utah). Examinations have been closed in the United Kingdom through at least 2010, in Canada through at least 2008 and in the Philippines through at least 2011. 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): 2015 2014 Beginning balance $ 220 $ 211 Additions based on tax positions related to the current year 3 11 Additions for tax positions of prior years 46 48 Reductions for tax positions of prior years (58 ) (50 ) Statute of limitations (6 ) (1 ) Settlements (6 ) — Interest and penalties (1 ) 1 Ending balance $ 198 $ 220 As of December 31, 2015 and 2014 , the Company had unrecognized tax benefits totaling $163 million and $188 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): 2015 2014 2013 Current: Federal $ 130 $ 2 $ 54 State 26 10 13 Total 156 12 67 Deferred: Federal 148 260 204 State 29 43 29 Total 177 303 233 Investment tax credits (5 ) (6 ) (3 ) Total income tax expense $ 328 $ 309 $ 297 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: 2015 2014 2013 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 ) (7 ) (7 ) Other — — (1 ) Effective income tax rate 32 % 31 % 30 % 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): 2015 2014 Deferred income tax assets: Regulatory liabilities $ 374 $ 362 Employee benefits 189 184 Derivative contracts and unamortized contract values 94 79 State carryforwards 68 68 Loss contingencies 67 70 Asset retirement obligations 81 47 Other 88 92 961 902 Deferred income tax liabilities: Property, plant and equipment (5,030 ) (4,780 ) Regulatory assets (639 ) (647 ) Other (42 ) (56 ) (5,711 ) (5,483 ) Net deferred income tax liability $ (4,750 ) $ (4,581 ) The following table provides PacifiCorp's net operating loss and tax credit carryforwards and expiration dates as of December 31, 2015 (in millions): State Net operating loss carryforwards $ 1,416 Deferred income taxes on net operating loss carryforwards $ 52 Expiration dates 2016 - 2032 Tax credit carryforwards $ 16 Expiration dates 2016 - indefinite The United States Internal Revenue Service has closed its examination of PacifiCorp's income tax returns through December 31, 2009. State agencies have closed their examinations of PacifiCorp's income tax returns through March 31, 2006, except for the December 31, 1995 and 1997 tax years in Utah. As of December 31, 2015 and 2014 , PacifiCorp had unrecognized tax benefits totaling $13 million and $14 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 consists of the following for the years ended December 31 (in millions): 2015 2014 2013 Current: Federal $ (405 ) $ (401 ) $ (196 ) State (10 ) (3 ) (10 ) (415 ) (404 ) (206 ) Deferred: Federal 281 299 101 State (6 ) 2 3 275 301 104 Investment tax credits (1 ) (1 ) (1 ) Total $ (141 ) $ (104 ) $ (103 ) A reconciliation of the federal statutory income tax rate to MidAmerican Energy's effective income tax rate applicable to income before income tax benefit is as follows for the years ended December 31: 2015 2014 2013 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (65 ) (59 ) (70 ) State income tax, net of federal income tax benefit (3 ) — (2 ) Effects of ratemaking (12 ) (8 ) (3 ) Other, net 1 (1 ) (2 ) Effective income tax rate (44 )% (33 )% (42 )% 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): 2015 2014 Deferred income tax assets: Regulatory liabilities $ 327 $ 332 Employee benefits 66 68 Derivative contracts 29 30 Asset retirement obligations 214 185 Other 59 59 Total deferred income tax assets 695 674 Deferred income tax liabilities: Depreciable property (3,321 ) (2,945 ) Regulatory assets (418 ) (366 ) Other (17 ) (25 ) Total deferred income tax liabilities (3,756 ) (3,336 ) Net deferred income tax liability $ (3,061 ) $ (2,662 ) As of December 31, 2015 , MidAmerican Energy has available $23 million of state carryforwards, principally related to $488 million of net operating losses, that expire at various intervals between 2016 and 2034 . The United States Internal Revenue Service has closed its examination of BHE's income tax returns through December 2009, including components related to MidAmerican Energy. In addition, state jurisdictions have closed their examinations of MidAmerican Energy's income tax returns through at least February 9, 2006, including Iowa and Illinois, which are closed through December 31, 2012, and December 31, 2008, respectively . 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): 2015 2014 Beginning balance $ 26 $ 29 Additions based on tax positions related to the current year 3 6 Additions for tax positions of prior years 47 38 Reductions based on tax positions related to the current year (6 ) (4 ) Reductions for tax positions of prior years (46 ) (40 ) Statute of limitations (5 ) (3 ) Settlements (6 ) — Interest and penalties (3 ) — Ending balance $ 10 $ 26 As of December 31, 2015 , MidAmerican Energy had unrecognized tax benefits totaling $26 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 consists of the following for the years ended December 31 (in millions): 2015 2014 2013 Current: Federal $ (408 ) $ (404 ) $ (200 ) State (12 ) (4 ) (12 ) (420 ) (408 ) (212 ) Deferred: Federal 282 297 100 State (5 ) 2 3 277 299 103 Investment tax credits (1 ) (1 ) (1 ) Total $ (144 ) $ (110 ) $ (110 ) A reconciliation of the federal statutory income tax rate MidAmerican Funding's the effective income tax rate applicable to income before income tax benefit is as follows for the years ended December 31: 2015 2014 2013 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (67 ) (61 ) (75 ) State income tax, net of federal income tax benefit (3 ) (1 ) (3 ) Effects of ratemaking (12 ) (9 ) (3 ) Other, net 1 (1 ) (2 ) Effective income tax rate (46 )% (37 )% (48 )% 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): 2015 2014 Deferred income tax assets: Regulatory liabilities $ 327 $ 332 Employee benefits 66 68 Derivative contracts 29 30 Asset retirement obligations 214 185 Other 68 70 Total deferred income tax assets 704 685 Deferred income tax liabilities: Depreciable property (3,326 ) (2,950 ) Regulatory assets (418 ) (366 ) Other (16 ) (25 ) Total deferred income tax liabilities (3,760 ) (3,341 ) Net deferred income tax liability $ (3,056 ) $ (2,656 ) As of December 31, 2015 , MidAmerican Funding has available $23 million of state carryforwards, principally related to $488 million of net operating losses, that expire at various intervals between 2016 and 2034 . The United States Internal Revenue Service has closed its examination of BHE's income tax returns through December 2009, including components related to MidAmerican Funding. In addition, state jurisdictions have closed their examinations of MidAmerican Funding's income tax returns through at least February 9, 2006, including Iowa and Illinois, which are closed through December 31, 2012, and December 31, 2008, respectively. 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): 2015 2014 Beginning balance $ 26 $ 29 Additions based on tax positions related to the current year 4 6 Additions for tax positions of prior years 46 38 Reductions based on tax positions related to the current year (6 ) (4 ) Reductions for tax positions of prior years (46 ) (40 ) Statute of limitations (5 ) (3 ) Settlements (6 ) — Interest and penalties (3 ) — Ending balance $ 10 $ 26 As of December 31, 2015 , MidAmerican Funding had unrecognized tax benefits totaling $27 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): 2015 2014 2013 Current – Federal $ — $ — $ (1 ) Deferred – Federal 163 131 96 Investment tax credits (1 ) (1 ) (1 ) Total income tax expense $ 162 $ 130 $ 94 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 : 2015 2014 2013 Federal statutory income tax rate 35 % 35 % 35 % Non-deductible BHE Merger related expenses — — 3 Effects of ratemaking 1 1 1 Effective income tax rate 36 % 36 % 39 % The net deferred income tax liability consists of the following as of December 31 (in millions): 2015 2014 Deferred income tax assets: Federal net operating loss and credit carryforwards $ 15 $ 158 Capital and financial leases 174 178 Employee benefits 30 22 Regulatory liabilities 47 37 Other 39 57 Total deferred income tax assets 305 452 Valuation allowance (5 ) (2 ) Total deferred income tax assets, net 300 450 Deferred income tax liabilities: Property related items (1,242 ) (1,175 ) Regulatory assets (275 ) (341 ) Capital and financial leases (169 ) (174 ) Other (19 ) (29 ) Total deferred income tax liabilities (1,705 ) (1,719 ) Net deferred income tax liability $ (1,405 ) $ (1,269 ) The following table provides Nevada Power 's federal net operating loss and tax credit carryforwards and expiration dates as of December 31 , 2015 (in millions): Net operating loss carryforwards $ 4 Deferred income taxes on federal net operating loss carryforwards $ 1 Expiration dates 2031 - 2035 Other tax credits $ 14 Expiration dates 2016 - 2035 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): 2015 2014 2013 Current – Federal $ — $ — $ (2 ) Deferred: Federal 48 48 38 State — — (2 ) Total deferred 48 48 36 Investment tax credits (1 ) (1 ) (1 ) Total income tax expense $ 47 $ 47 $ 33 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 : 2015 2014 2013 Federal statutory income tax rate 35 % 35 % 35 % Non-deductible BHE Merger related expenses — — 1 Effects of ratemaking 1 1 1 Other — (1 ) — Effective income tax rate 36 % 35 % 37 % The net deferred income tax liability consists of the following as of December 31 (in millions): 2015 2014 Deferred income tax assets: Net operating loss and credit carryforwards $ 39 $ 56 Employee benefit plans 25 22 Regulatory liabilities 19 21 Capital and financial lease liabilities 13 9 Customer Advances 8 7 Other 12 15 Total deferred income tax assets $ 116 $ 130 Deferred income tax liabilities: Property related items $ (538 ) $ (478 ) Regulatory assets (121 ) (147 ) Capital and financial leases (13 ) (9 ) Other (14 ) (20 ) Total deferred income tax liabilities $ (686 ) $ (654 ) Net deferred income tax liability $ (570 ) $ (524 ) The following table provides Sierra Pacific 's federal net operating loss and tax credit carryforwards and expiration dates as of December 31 , 2015 (in millions): Net operating loss carryforwards $ 95 Deferred income taxes on federal net operating loss carryforwards $ 33 Expiration dates 2031 - 2035 Other tax credits $ 5 Expiration dates 2016 - 2035 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, 2015
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): 2015 2014 2013 Supplemental disclosure of cash flow information: Interest paid, net of amounts capitalized $ 1,764 $ 1,585 $ 1,073 Income taxes received, net (1) $ 1,666 $ 635 $ 1,105 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 718 $ 1,143 $ 661 (1) Includes $1.8 billion , $764 million and $1.2 billion of income taxes received from Berkshire Hathaway in 2015 , 2014 and 2013 , 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): 2015 2014 2013 Interest paid, net of amounts capitalized $ 342 $ 340 $ 340 Income taxes paid, net $ 40 $ 161 $ 120 Supplemental disclosure of non-cash investing and financing activities: Accounts payable related to property, plant and equipment additions $ 147 $ 140 $ 157 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): 2015 2014 2013 Supplemental cash flow information: Interest paid, net of amounts capitalized $ 154 $ 144 $ 109 Income taxes received, net $ 629 $ 149 $ 36 Supplemental disclosure of non-cash investing transactions: Accounts payable related to utility plant additions $ 249 $ 128 $ 117
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): 2015 2014 2013 Supplemental cash flow information: Interest paid, net of amounts capitalized $ 177 $ 167 $ 132 Income taxes received, net $ 630 $ 153 $ 42 Supplemental disclosure of non-cash investing transactions: Accounts payable related to utility plant additions $ 249 $ 128 $ 117
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): 2015 2014 2013 Supplemental disclosure of cash flow information - Interest paid, net of amounts capitalized $ 186 $ 194 $ 209 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 51 $ 30 $ 25 Capital and financial lease obligations incurred $ (5 ) $ 7 $ 419
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): 2015 2014 2013 Supplemental disclosure of cash flow information - Interest paid, net of amounts capitalized $ 54 $ 54 $ 59 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 24 $ 31 $ 37 Capital and financial lease obligations incurred $ 13 $ 1 $ 22

Related Party Transactions Rela

Related Party Transactions Related Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2015
PacifiCorp [Member]
Related Party Transaction [Line Items]
Related Party Transactions Disclosure [Text Block]	Related-Party Transactions 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, 2015 and 2014 and $17 million during the year ended December 31, 2013 . Payables associated with these administrative services were $2 million and $1 million as of December 31, 2015 and 2014 , respectively. Amounts charged by PacifiCorp to BHE and its subsidiaries under this agreement totaled $7 million , $10 million and $9 million during the years ended December 31, 2015 , 2014 and 2013 , respectively. Receivables associated with these administrative services were $1 million and $7 million as of December 31, 2015 and 2014 , 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 $8 million , $7 million and $5 million during the years ended December 31, 2015 , 2014 and 2013 , respectively. Payables associated with these services were $1 million as of December 31, 2015 and 2014 . Amounts charged by PacifiCorp to subsidiaries of BHE for wholesale electricity sales in the ordinary course of business totaled $2 million , $5 million and $- million during the years ended December 31, 2015 , 2014 and 2013 , 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 $39 million during each of the years ended December 31, 2015 and 2014 and $32 million during the year ended December 31, 2013 . As of December 31, 2015 and 2014 , PacifiCorp had $1 million and $3 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. Receivables for claims were $- million and $2 million as of December 31, 2015 and 2014 , respectively. Proceeds from claims were $2 million , $- million and $1 million during the years ended December 31, 2015 , 2014 and 2013 , 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 and $133 million as of December 31, 2015 and 2014, respectively. For the years ended December 31, 2015 , 2014 and 2013 , cash paid for federal and state income taxes to BHE totaled $40 million , $161 million and $120 million , respectively. PacifiCorp transacts with its equity investees, Bridger Coal and Trapper Mining Inc. During the years ended December 31, 2015 , 2014 and 2013 , PacifiCorp charged Bridger Coal $19 million , $3 million and $2 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 $4 million as of December 31, 2015 and 2014 . Services provided by equity investees to PacifiCorp primarily relate to coal purchases. During the years ended December 31, 2015 , 2014 and 2013 , coal purchases from PacifiCorp's equity investees totaled $181 million , $146 million and $152 million , respectively. Payables to PacifiCorp's equity investees were $16 million and $19 million as of December 31, 2015 and 2014 , 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 $46 million , $58 million and $38 million for 2015 , 2014 and 2013 , respectively. MidAmerican Energy reimbursed BHE in the amount of $7 million , $8 million and $10 million in 2015 , 2014 and 2013 , 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 $165 million , $144 million and $155 million in 2015 , 2014 and 2013 , respectively. MidAmerican Energy had accounts receivable from affiliates of $5 million and $12 million as of December 31, 2015 and 2014 , respectively, that are included in receivables on the Balance Sheets. MidAmerican Energy also had accounts payable to affiliates of $13 million and $12 million as of December 31, 2015 and 2014 , respectively, 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. As of December 31, 2015 and 2014 , MidAmerican Energy had current federal and state income taxes receivable from BHE of $102 million and $299 million , respectively. MidAmerican Energy received net cash receipts for federal and state income taxes from BHE totaling $629 million , $149 million and $36 million for the years ended December 31, 2015 , 2014 and 2013 , 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 $10 million and $13 million as of December 31, 2015 and 2014 , respectively, and similar amounts payable to affiliates totaled $29 million and $30 million as of December 31, 2015 and 2014 , respectively. See Note 10 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 , $37 million and $28 million for 2015 , 2014 and 2013 , respectively. MidAmerican Funding reimbursed BHE in the amount of $7 million , $8 million and $10 million in 2015 , 2014 and 2013 , 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 $165 million , $144 million and $155 million in 2015 , 2014 and 2013 , 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 $139 million at an interest rate of 0.494% as of December 31, 2015 , and $136 million at an interest rate of 0.408% as of December 31, 2014 , 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 2015 and 2014 . MidAmerican Funding had accounts receivable from affiliates of $7 million as of December 31, 2015 and 2014 , respectively, that are included in receivables, net on the Consolidated Balance Sheets. MidAmerican Funding also had accounts payable to affiliates of $12 million and $12 million as of December 31, 2015 and 2014 , respectively, 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. As of December 31, 2015 and 2014 , MidAmerican Funding had current federal and state income taxes receivable from BHE of $102 million and $296 million , respectively. MidAmerican Funding received net cash receipts for federal and state income taxes from BHE totaling $631 million , $154 million and $42 million for the years ended December 31, 2015 , 2014 and 2013 , 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 $10 million and $13 million as of December 31, 2015 and 2014 , respectively, and similar amounts payable to affiliates totaled $29 million and $30 million as of December 31, 2015 and 2014 , respectively. See Note 10 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 , 2015 , 2014 and 2013 . As of December 31 , 2015 and 2014 , 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 $3 million for each of the years ended December 31 , 2015 , 2014 and 2013 . There were no receivables associated with these services as of December 31 , 2015 and 2014 . PacifiCorp provided electricity and the sale of renewable energy credits to Nevada Power of $2 million , $5 million and $2 million for the years ended December 31 , 2015 , 2014 and 2013 , respectively. Payables associated with these transactions were $- million and $4 million as of December 31 , 2015 and 2014 , respectively. Nevada Power provided electricity to Sierra Pacific of $69 million , $33 million and $36 million for the years ended December 31 , 2015 , 2014 and 2013 , respectively. Receivables associated with these transactions were $15 million and $7 million as of December 31 , 2015 and 2014 , respectively. Nevada Power purchased electricity from Sierra Pacific of $2 million , $8 million and $1 million for the years ended December 31 , 2015 , 2014 and 2013 , respectively. Payables associated with these transactions were $1 million and $- million as of December 31 , 2015 and 2014 , 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 , $1 million , and $- million for the years ending December 31 , 2015 , 2014 and 2013 , respectively. NV Energy provided services to Nevada Power of $12 million , $19 million and $45 million for the years ending December 31 , 2015 , 2014 and 2013 , respectively. Nevada Power provided services to Sierra Pacific of $22 million , $20 million and $24 million for the years ended December 31 , 2015 , 2014 and 2013 , respectively. Sierra Pacific provided services to Nevada Power of $16 million , $16 million and $22 million for the years ended December 31 , 2015 , 2014 and 2013 , respectively. As of December 31 , 2015 and 2014 , Nevada Power 's Consolidated Balance Sheets included amounts due to NV Energy of $40 million and $33 million , respectively. There were no receivables due from NV Energy as of December 31 , 2015 and 2014 . As of December 31 , 2015 and 2014 , Nevada Power 's Consolidated Balance Sheets included receivables due from Sierra Pacific of $6 million and $5 million , respectively. There were no payables due to Sierra Pacific as of December 31 , 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 $2 million , $8 million and $1 million for the years ended December 31 , 2015 , 2014 and 2013 , respectively. Receivables associated with these transactions were $1 million and $4 million as of December 31 , 2015 and 2014 . Sierra Pacific purchased electricity from Nevada Power of $69 million , $33 million and $36 million for the years ended December 31 , 2015 , 2014 and 2013 , respectively. Payables associated with these transactions were $15 million and $7 million as of December 31 , 2015 and 2014 , 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 $6 million , $9 million and $19 million for the years ending December 31 , 2015 , 2014 and 2013 , respectively. Sierra Pacific provided services to Nevada Power of $16 million , $16 million , and $- million for the years ended December 31 , 2015 , 2014 and 2013 , respectively. Nevada Power provided services to Sierra Pacific of $22 million , $20 million , and $- million for the years ended December 31 , 2015 , 2014 and 2013 , respectively. As of December 31 , 2015 and 2014 , Sierra Pacific 's Consolidated Balance Sheets included amounts due to NV Energy of $21 million and $20 million , respectively. There were no receivables due from NV Energy as of December 31 , 2015 and 2014 . As of December 31 , 2015 and 2014 , Sierra Pacific 's Consolidated Balance Sheets included payables due to Nevada Power of $6 million and $5 million , respectively. There were no receivables due from Nevada Power as of December 31 , 2015 and 2014 . 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, 2015
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 2015 2014 2013 2015 2014 2013 Service cost $ 33 $ 36 $ 24 $ 11 $ 14 $ 14 Interest cost 121 131 87 31 46 33 Expected return on plan assets (169 ) (164 ) (119 ) (45 ) (53 ) (44 ) Net amortization 53 44 58 (11 ) (3 ) 6 Net periodic benefit cost (credit) $ 38 $ 47 $ 50 $ (14 ) $ 4 $ 9 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 2015 2014 2015 2014 Plan assets at fair value, beginning of year $ 2,718 $ 2,711 $ 858 $ 852 Employer contributions 13 37 2 2 Participant contributions — — 9 11 Actual return on plan assets (17 ) 188 — 54 Settlement (23 ) — (150 ) — Benefits paid (202 ) (218 ) (57 ) (61 ) Plan assets at fair value, end of year $ 2,489 $ 2,718 $ 662 $ 858 The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2015 2014 2015 2014 Benefit obligation, beginning of year $ 3,119 $ 2,821 $ 936 $ 987 Service cost 33 36 11 14 Interest cost 121 131 31 46 Participant contributions — — 9 11 Actuarial loss (gain) (110 ) 349 (43 ) (61 ) Amendment (4 ) — 3 — Settlement (23 ) — (150 ) — Benefits paid (202 ) (218 ) (57 ) (61 ) Benefit obligation, end of year $ 2,934 $ 3,119 $ 740 $ 936 Accumulated benefit obligation, end of year $ 2,906 $ 3,086 In conjunction with the Utah Mine Disposition described in Note 6 , 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 actuarial gain associated with the other postretirement benefit obligation during the year ended December 31, 2014 includes a gain that reduced the benefit obligation associated with the UMWA plan participants to $150 million . 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 2015 2014 2015 2014 Plan assets at fair value, end of year $ 2,489 $ 2,718 $ 662 $ 858 Benefit obligation, end of year 2,934 3,119 740 936 Funded status $ (445 ) $ (401 ) $ (78 ) $ (78 ) Amounts recognized on the Consolidated Balance Sheets: Other assets $ 7 $ 12 $ 15 $ 10 Other current liabilities (15 ) (14 ) — — Other long-term liabilities (437 ) (399 ) (93 ) (88 ) Amounts recognized $ (445 ) $ (401 ) $ (78 ) $ (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 $228 million and $247 million as of December 31, 2015 and 2014 , 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 2015 2014 2015 2014 Fair value of plan assets $ 1,811 $ 1,987 $ 413 $ 598 Projected benefit obligation $ 2,263 $ 2,401 $ 505 $ 686 Accumulated benefit obligation $ 2,244 $ 2,380 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 2015 2014 2015 2014 Net loss $ 768 $ 757 $ 97 $ 108 Prior service credit (25 ) (31 ) (68 ) (87 ) Regulatory deferrals (2 ) (3 ) 8 2 Total $ 741 $ 723 $ 37 $ 23 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2015 and 2014 is as follows (in millions): Accumulated Other Regulatory Regulatory Comprehensive Asset Liability Loss Total Pension Balance, December 31, 2013 $ 490 $ (58 ) $ 9 $ 441 Net loss arising during the year 258 52 16 326 Net amortization (38 ) — (6 ) (44 ) Total 220 52 10 282 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 Regulatory Regulatory Asset Liability Total Other Postretirement Balance, December 31, 2013 $ 99 $ (16 ) $ 83 Net (gain) loss arising during the year (64 ) 1 (63 ) Net amortization 2 1 3 Total (62 ) 2 (60 ) 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 The net loss, prior service credit and regulatory deferrals that will be amortized in 2016 into net periodic benefit cost are estimated to be as follows (in millions): Net Prior Service Regulatory Loss Credit Deferrals Total Pension $ 58 $ (11 ) $ (1 ) $ 46 Other postretirement 3 (16 ) 1 (12 ) Total $ 61 $ (27 ) $ — $ 34 Plan Assumptions Weighted-average assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2015 2014 2013 2015 2014 2013 Benefit obligations as of December 31: Discount rate 4.43 % 4.00 % 4.81 % 4.33 % 3.88 % 4.82 % Rate of compensation increase 2.75 % 2.75 % 3.00 % N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.00 % 4.81 % 4.03 % 3.93 % 4.82 % 4.01 % Expected return on plan assets 6.88 % 6.86 % 7.50 % 7.00 % 7.34 % 7.44 % Rate of compensation increase 2.75 % 3.00 % 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. 2015 2014 Assumed healthcare cost trend rates as of December 31: Healthcare cost trend rate assumed for next year 7.70 % 8.00 % 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, 2015 $ 1 $ (1 ) Other postretirement benefit obligation as of December 31, 2015 5 (5 ) Contributions and Benefit Payments Employer contributions to the pension and other postretirement benefit plans are expected to be $34 million and $1 million , respectively, during 2016 . 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 2016 through 2020 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Other Pension Postretirement 2016 $ 221 $ 56 2017 224 57 2018 226 58 2019 224 58 2020 225 61 2021-2025 1,054 272 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, 2015 : 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 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, 2015 Cash equivalents $ — $ 31 $ — $ 31 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) 144 821 — 965 Limited partnership interests (3) — — 65 65 Real estate funds — — 47 47 Total $ 1,007 $ 1,370 $ 112 $ 2,489 As of December 31, 2014 Cash equivalents $ 15 $ 54 $ — $ 69 Debt securities: United States government obligations 166 — — 166 International government obligations — 11 — 11 Corporate obligations — 268 — 268 Municipal obligations — 27 — 27 Agency, asset and mortgage-backed obligations — 94 — 94 Equity securities: United States companies 698 — — 698 International companies 122 — — 122 Investment funds (2) 301 852 — 1,153 Limited partnership interests (3) — — 70 70 Real estate funds — — 40 40 Total $ 1,302 $ 1,306 $ 110 $ 2,718 (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 66% and 34% , respectively, for 2015 and 61% and 39% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 58% and 42% , respectively, for 2015 and 64% and 36% , respectively, for 2014 . (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, 2015 Cash equivalents (2) $ 12 $ 2 $ — $ 14 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 (3) 149 153 — 302 Limited partnership interests (4) — — 4 4 Total $ 401 $ 257 $ 4 $ 662 As of December 31, 2014 Cash equivalents $ 145 $ 1 $ — $ 146 Debt securities: United States government obligations 17 — — 17 Corporate obligations — 34 — 34 Municipal obligations — 43 — 43 Agency, asset and mortgage-backed obligations — 31 — 31 Equity securities: United States companies 243 — — 243 International companies 6 — — 6 Investment funds (3) 202 131 — 333 Limited partnership interests (4) — — 5 5 Total $ 613 $ 240 $ 5 $ 858 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) In December 2014, PacifiCorp began to migrate funds to cash and cash equivalents in anticipation of the $150 million to be transferred to a fund managed by the UMWA in May 2015 as a result of the other postretirement settlement. Remaining investments were rebalanced to align to PacifiCorp's target investment allocations. (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 2015 and 63% and 37% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 70% and 30% , respectively, for 2015 and 69% and 31% , respectively, for 2014 . (4) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. 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. When observable market data is not available, the fair value is determined using unobservable inputs, such as estimated future cash flows, purchase multiples paid in other comparable third-party transactions or other information. Investments in limited partnerships are valued at estimated fair value based on the Plan's proportionate share of the partnerships' fair value as recorded in the partnerships' most recently available financial statements adjusted for recent activity and forecasted returns. The fair values recorded in the partnerships' financial statements are generally determined based on closing public market prices for publicly traded securities and as determined by the general partners for other investments based on factors including estimated future cash flows, purchase multiples paid in other comparable third-party transactions, comparable public company trading multiples and other information. The real estate funds determine fair value of their underlying assets using independent appraisals given there is no current liquid market for the underlying assets. The following table reconciles the beginning and ending balances of the Company's plan assets measured at fair value using significant Level 3 inputs for the years ended December 31 (in millions): Other Pension Postretirement- Limited Real Limited Partnership Estate Partnership Interests Funds Interests Balance, December 31, 2012 $ 96 $ 26 $ 7 Actual return on plan assets still held at period end 16 5 1 Purchases, sales, distributions and settlements (26 ) — (2 ) Balance, December 31, 2013 86 31 6 Actual return on plan assets still held at period end (1 ) 4 — Purchases, sales, distributions and settlements (15 ) 5 (1 ) Balance, December 31, 2014 70 40 5 Actual return on plan assets still held at period end 5 7 — Purchases, sales, distributions and settlements (10 ) — (1 ) Balance, December 31, 2015 $ 65 $ 47 $ 4 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): 2015 2014 2013 Service cost $ 24 $ 24 $ 22 Interest cost 79 95 85 Expected return on plan assets (116 ) (124 ) (101 ) Net amortization 62 51 53 Net periodic benefit cost $ 49 $ 46 $ 59 Funded Status The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): 2015 2014 Plan assets at fair value, beginning of year $ 2,368 $ 2,177 Employer contributions 77 89 Participant contributions 2 2 Actual return on plan assets 48 337 Benefits paid (91 ) (92 ) Foreign currency exchange rate changes (128 ) (145 ) Plan assets at fair value, end of year $ 2,276 $ 2,368 The following table is a reconciliation of the benefit obligation for the years ended December 31 (in millions): 2015 2014 Benefit obligation, beginning of year $ 2,279 $ 2,185 Service cost 24 24 Interest cost 79 95 Participant contributions 2 2 Actuarial (gain) loss (30 ) 205 Benefits paid (91 ) (92 ) Foreign currency exchange rate changes (121 ) (140 ) Benefit obligation, end of year $ 2,142 $ 2,279 Accumulated benefit obligation, end of year $ 1,891 $ 2,019 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): 2015 2014 Plan assets at fair value, end of year $ 2,276 $ 2,368 Benefit obligation, end of year 2,142 2,279 Funded status $ 134 $ 89 Amounts recognized on the Consolidated Balance Sheets: Other assets $ 134 $ 89 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): 2015 2014 Net loss $ 592 $ 655 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): 2015 2014 Balance, beginning of year $ 655 $ 751 Net loss (gain) arising during the year 38 (8 ) Net amortization (62 ) (51 ) Foreign currency exchange rate changes (39 ) (37 ) Total (63 ) (96 ) Balance, end of year $ 592 $ 655 The net loss that will be amortized from accumulated other comprehensive loss in 2016 into net periodic benefit cost is estimated to be $48 million . Plan Assumptions Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: 2015 2014 2013 Benefit obligations as of December 31: Discount rate 3.70 % 3.60 % 4.40 % Rate of compensation increase 2.90 % 2.80 % 3.15 % Rate of future price inflation 2.90 % 2.80 % 3.15 % Net periodic benefit cost for the years ended December 31: Discount rate 3.60 % 4.40 % 4.40 % Expected return on plan assets 5.60 % 6.10 % 5.70 % Rate of compensation increase 2.80 % 3.15 % 2.80 % Rate of future price inflation 2.80 % 3.15 % 2.80 % Contributions and Benefit Payments Employer contributions to the UK Plan are expected to be £40 million during 2016 . The expected benefit payments to participants in the UK Plan for 2016 through 2020 and for the five years thereafter, using the foreign currency exchange rate as of December 31, 2015 , are summarized below (in millions): 2016 $ 88 2017 90 2018 92 2019 95 2020 97 2021-2025 522 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, 2015 : % 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 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, 2015 Cash equivalents $ 46 $ — $ — $ 46 Debt securities: United Kingdom government obligations 424 — — 424 Other international government obligations — 13 — 13 Corporate obligations — 186 — 186 Investment funds (2) 109 1,294 — 1,403 Real estate funds — — 204 204 Total $ 579 $ 1,493 $ 204 $ 2,276 As of December 31, 2014 Cash equivalents $ 43 $ — $ — $ 43 Debt securities: United States government obligations — — — — United Kingdom government obligations 452 — — 452 Other international government obligations — 14 — 14 Corporate obligations — 196 — 196 Investment funds (2) 114 1,350 — 1,464 Real estate funds — — 199 199 Total $ 609 $ 1,560 $ 199 $ 2,368 (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% for both 2015 and 2014 . 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 2015 2014 2013 Beginning balance $ 199 $ 179 $ 163 Actual return on plan assets still held at period end 18 33 12 Foreign currency exchange rate changes (13 ) (13 ) 4 Ending balance $ 204 $ 199 $ 179 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 $90 million , $83 million and $63 million for the years ended December 31, 2015 , 2014 and 2013 , 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 a non-contributory defined benefit pension plan, 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. The SERP was closed to new participants as of March 21, 2006 and froze future accruals for active participants as of December 31, 2014. 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 continue to earn benefits based on a 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. 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" below 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 2015 2014 2013 2015 2014 2013 Service cost $ 4 $ 5 $ 6 $ 3 $ 6 $ 9 Interest cost 53 57 54 16 28 25 Expected return on plan assets (77 ) (76 ) (74 ) (23 ) (31 ) (30 ) Net amortization 42 29 48 (4 ) 2 8 Net periodic benefit cost (credit) $ 22 $ 15 $ 34 $ (8 ) $ 5 $ 12 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 2015 2014 2015 2014 Plan assets at fair value, beginning of year $ 1,146 $ 1,171 $ 482 $ 486 Employer contributions 4 10 1 1 Participant contributions — — 6 7 Actual return on plan assets — 53 1 25 Settlement — — (150 ) — Benefits paid (107 ) (88 ) (35 ) (37 ) Plan assets at fair value, end of year $ 1,043 $ 1,146 $ 305 $ 482 The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2015 2014 2015 2014 Benefit obligation, beginning of year $ 1,378 $ 1,230 $ 539 $ 598 Service cost 4 5 3 6 Interest cost 53 57 16 28 Participant contributions — — 6 7 Actuarial (gain) loss (39 ) 174 (17 ) (63 ) Settlement — — (150 ) — Benefits paid (107 ) (88 ) (35 ) (37 ) Benefit obligation, end of year $ 1,289 $ 1,378 $ 362 $ 539 Accumulated benefit obligation, end of year $ 1,289 $ 1,378 The actuarial gain associated with the other postretirement benefit obligation during the year ended December 31, 2014 includes a gain that reduced the benefit obligation associated with the UMWA plan participants to $150 million . Refer to "Utah Mine Disposition and Labor Agreement" above. 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 2015 2014 2015 2014 Plan assets at fair value, end of year $ 1,043 $ 1,146 $ 305 $ 482 Less - Benefit obligation, end of year 1,289 1,378 362 539 Funded status $ (246 ) $ (232 ) $ (57 ) $ (57 ) Amounts recognized on the Consolidated Balance Sheets: Other current liabilities $ (4 ) $ (4 ) $ — $ — Other long-term liabilities (242 ) (228 ) (57 ) (57 ) Amounts recognized $ (246 ) $ (232 ) $ (57 ) $ (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 $52 million and $51 million as of December 31, 2015 and 2014 , 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 2015 2014 2015 2014 Net loss $ 508 $ 520 $ 36 $ 41 Prior service credit (13 ) (21 ) (19 ) (26 ) Regulatory deferrals (3 ) (3 ) 9 2 Total $ 492 $ 496 $ 26 $ 17 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2015 and 2014 is as follows (in millions): Accumulated Other Regulatory Comprehensive Asset Loss Total Pension Balance, December 31, 2013 $ 313 $ 15 $ 328 Net loss arising during the year 189 8 197 Net amortization (28 ) (1 ) (29 ) Total 161 7 168 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 Regulatory Asset Other Postretirement Balance, December 31, 2013 $ 77 Net gain arising during the year (58 ) Net amortization (2 ) Total (60 ) Balance, December 31, 2014 17 Net loss arising during the year 5 Net amortization 4 Total 9 Balance, December 31, 2015 $ 26 The net loss, prior service credit and regulatory deferrals that will be amortized in 2016 into net periodic benefit cost are estimated to be as follows (in millions): Net Prior Service Regulatory Loss Credit Deferrals Total Pension $ 42 $ (8 ) $ (1 ) $ 33 Other postretirement 1 (7 ) 1 (5 ) Total $ 43 $ (15 ) $ — $ 28 Plan Assumptions Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2015 2014 2013 2015 2014 2013 Benefit obligations as of December 31: Discount rate 4.40 % 4.00 % 4.80 % 4.35 % 3.90 % 4.90 % Rate of compensation increase 2.75 2.75 3.00 N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.00 % 4.80 % 4.05 % 3.99 % 4.90 % 4.10 % Expected return on plan assets 7.50 7.50 7.50 7.08 7.50 7.50 Rate of compensation increase 2.75 3.00 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 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. The assumed healthcare cost trend rates used to determine the benefit obligation as of December 31, 2014 were as follows: Healthcare cost trend rate assumed for next year 8.00 % Rate that the cost trend rate gradually declines to 5.00 % Year that the rate reaches the rate it is assumed to remain at 2025 Contributions and Benefit Payments Employer contributions to the pension and other postretirement benefit plans are expected to be $4 million and $- million, respectively, during 2016 . 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 2016 through 2020 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Pension Other Postretirement 2016 $ 108 $ 28 2017 110 28 2018 108 28 2019 109 27 2020 107 30 2021-2025 448 122 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, 2015 : 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 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, 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) 83 351 — 434 Limited partnership interests (3) — — 65 65 Total $ 527 $ 451 $ 65 $ 1,043 As of December 31, 2014 Cash equivalents $ — $ 8 $ — $ 8 Debt securities: United States government obligations 15 — — 15 Corporate obligations — 53 — 53 Municipal obligations — 8 — 8 Agency, asset and mortgage-backed obligations — 48 — 48 Equity securities: United States companies 488 — — 488 International companies 16 — — 16 Investment funds (2) 217 223 — 440 Limited partnership interests (3) — — 70 70 Total $ 736 $ 340 $ 70 $ 1,146 (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 53% and 47% , respectively, for 2015 and 50% and 50% , respectively, for 2014 , and are invested in United States and international securities of approximately 40% and 60% , respectively, for 2015 and 43% and 57% , respectively, for 2014 . (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, 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) 32 126 — 158 Limited partnership interests (3) — — 4 4 Total $ 144 $ 157 $ 4 $ 305 As of December 31, 2014 Cash and cash equivalents (4) $ 139 $ — $ — $ 139 Debt securities: United States government obligations 8 — — 8 Corporate obligations — 18 — 18 Municipal obligations — 2 — 2 Agency, asset and mortgage-backed obligations — 16 — 16 Equity securities: United States companies 112 — — 112 International companies 4 — — 4 Investment funds (2) 84 94 — 178 Limited partnership interests (3) — — 5 5 Total $ 347 $ 130 $ 5 $ 482 (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 61% and 39% , respectively, for 2015 and 63% and 37% , respectively, for 2014 , and are invested in United States and international securities of approximately 67% and 33% , respectively, for 2015 and 64% and 36% , respectively, for 2014 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. (4) In December 2014, PacifiCorp began to migrate funds to cash and cash equivalents in anticipation of the $150 million to be transferred to a fund managed by the UMWA in May 2015 as a result of the other postretirement settlement. Remaining investments were rebalanced to align to target investment allocations. 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 or unquoted net asset values based on observable market inputs. For level 3 investments, the fair value is determined using unobservable inputs, such as estimated future cash flows, purchase multiples paid in other comparable third-party transactions or other information. Most investments in limited partnership interests are valued at estimated fair value based on the pension and other postretirement benefit plans' proportionate shares of the partnerships' fair value as recorded in the partnerships' most recently available financial statements adjusted for recent activity and estimated returns. The fair values recorded in the partnerships' financial statements are generally determined based on closing public market prices for publicly traded securities and as determined by the general partners for other investments based on factors including estimated future cash flows, purchase multiples paid in other comparable third-party transactions, comparable public company trading multiples and other information. One of the limited partnerships is valued at the unit price calculated by the general partner primarily based on independent appraised values of the underlying property holdings. The following table reconciles the beginning and ending balances of PacifiCorp's plan assets measured at fair value using significant Level 3 inputs for the years ended December 31 (in millions): Limited Partnership Interests Pension Other Postretirement Balance, December 31, 2012 $ 96 $ 7 Actual return on plan assets still held at December 31, 2013 16 1 Purchases, sales, distributions and settlements (26 ) (2 ) Balance, December 31, 2013 86 6 Actual return on plan assets still held at December 31, 2014 (1 ) — Purchases, sales, distributions and settlements (15 ) (1 ) Balance, December 31, 2014 70 5 Actual return on plan assets still held at December 31, 2015 5 — Purchases, sales, distributions and settlements (10 ) (1 ) Balance, December 31, 2015 $ 65 $ 4 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 best 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. The estimate of the withdrawal obligation provided by the UMWA 1974 Pension Plan is $97 million for a withdrawal occurring by July 1, 2015. Energy West Mining Company may elect to make a lump sum payment or annual installment payments to settle the withdrawal obligation. 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 2015 2014 2013 Funding improvement plan Surcharge imposed under PPA (1) 2015 2014 2013 Year contributions to plan exceeded more than 5% of total contributions (2) UMWA 1974 Pension Plan 52-1050282 Critical and Declining Critical Seriously Endangered Implemented Yes $ 1 $ 2 $ 3 None Local 57 Trust Fund 87-0640888 At least 80% At least 80% At least 80% None None $ 8 $ 9 $ 9 2014, 2013, 2012 (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, 2013 and 2012. Information for the plan years beginning July 1, 2015 and 2014 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 January 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 certain 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 $35 million , $34 million and $35 million for the years ended December 31, 2015 , 2014 and 2013 , 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 2015 , 2014 and 2013 , MidAmerican Energy's share of the pension net periodic benefit cost (credit) was $(4) million , $1 million and $11 million , respectively. MidAmerican Energy's share of the other postretirement net periodic benefit cost (credit) in 2015 , 2014 and 2013 totaled $- million, $- million and $(1) 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 2015 2014 2013 2015 2014 2013 Service cost $ 12 $ 14 $ 18 $ 7 $ 6 $ 5 Interest cost 32 35 33 9 10 8 Expected return on plan assets (46 ) (45 ) (45 ) (15 ) (15 ) (13 ) Net amortization 2 1 11 (3 ) (3 ) (3 ) Net periodic benefit cost (credit) $ — $ 5 $ 17 $ (2 ) $ (2 ) $ (3 ) 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 2015 2014 2015 2014 Plan assets at fair value, beginning of year $ 730 $ 722 $ 259 $ 256 Employer contributions 7 7 1 1 Participant contributions — — 1 1 Actual return on plan assets 4 52 — 13 Benefits paid (63 ) (51 ) (12 ) (12 ) Plan assets at fair value, end of year $ 678 $ 730 $ 249 $ 259 The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2015 2014 2015 2014 Benefit obligation, beginning of year $ 840 $ 768 $ 249 $ 235 Service cost 12 14 7 6 Interest cost 32 35 9 10 Participant contributions — — 1 1 Actuarial (gain) loss (36 ) 74 (20 ) 9 Benefits paid (63 ) (51 ) (12 ) (12 ) Benefit obligation, end of year $ 785 $ 840 $ 234 $ 249 Accumulated benefit obligation, end of year $ 773 $ 825 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 2015 2014 2015 2014 Plan assets at fair value, end of year $ 678 $ 730 $ 249 $ 259 Less - Benefit obligation, end of year 785 840 234 249 Funded status $ (107 ) $ (110 ) $ 15 $ 10 Amounts recognized on the Balance Sheets: Other assets $ 7 $ 12 $ 15 $ 10 Other current liabilities (8 ) (8 ) — — Other liabilities (106 ) (114 ) — — Amounts recognized $ (107 ) $ (110 ) $ 15 $ 10 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 $156 million and $156 million as of December 31, 2015 and 2014 , respectively, of which $104 million and $103 million was held by MidAmerican Energy as of December 31, 2015 and 2014 , 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 2015 2014 2015 2014 Net loss $ 26 $ 21 $ 42 $ 49 Prior service cost (credit) 2 3 (36 ) (42 ) Total $ 28 $ 24 $ 6 $ 7 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, 2015 and 2014 is as follows (in millions): Regulatory Asset Regulatory Liability Receivables (Payables) with Affiliates Total Pension Balance, December 31, 2013 $ 16 $ (55 ) $ (2 ) $ (41 ) Net loss arising during the year 6 51 9 66 Net amortization — (1 ) — (1 ) Total 6 50 9 65 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 Regulatory Asset Regulatory Liability Receivables (Payables) with Affiliates Total Other Postretirement Balance, December 31, 2013 $ 10 $ — $ (16 ) $ (6 ) Net loss arising during the year 8 — 2 10 Net amortization 2 — 1 3 Total 10 — 3 13 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 The net loss and prior service cost (credit) that will be amortized in 2016 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 2015 2014 2013 2015 2014 2013 Benefit obligations as of December 31: Discount rate 4.50 % 4.00 % 4.75 % 4.25 % 3.75 % 4.50 % Rate of compensation increase 2.75 % 2.75 % 3.00 % N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.00 % 4.75 % 4.00 % 3.75 % 4.50 % 3.75 % Expected return on plan assets (1) 7.25 % 7.50 % 7.50 % 7.00 % 7.25 % 7.25 % Rate of compensation increase 2.75 % 3.00 % 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 5.18% for 2015 , and 5.37% for 2014 , and 5.56% for 2013 . 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. 2015 2014 Assumed healthcare cost trend rates as of December 31: Healthcare cost trend rate assumed for next year 7.70 % 8.00 % 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, 2015 $ 1 $ — Other postretirement benefit obligation as of December 31, 2015 3 (3 ) 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 2016 . 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 2016 through 2020 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Pension Other Postretirement 2016 $ 59 $ 17 2017 60 19 2018 60 20 2019 60 21 2020 61 21 2021-2025 291 102 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, 2015 : 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 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, 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) 61 289 — 350 Real estate funds — — 47 47 Total $ 236 $ 395 $ 47 $ 678 As of December 31, 2014 Cash equivalents $ — $ 24 $ — $ 24 Debt securities: United States government obligations 8 — — 8 Corporate obligations — 29 — 29 Municipal obligations — 4 — 4 Agency, asset and mortgage-backed obligations — 33 — 33 Equity securities: United States companies 149 — — 149 International equity securities 40 — — 40 Investment funds (2) 84 319 — 403 Real estate funds — — 40 40 Total $ 281 $ 409 $ 40 $ 730 (1) Refer to Note 13 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 72% and 28% , respectively, for 2015 and 68% and 32% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 73% and 27% , respectively, for 2015 and 74% and 26% , respectively, for 2014 . 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, 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 $ 186 $ 63 $ — $ 249 As of December 31, 2014 Cash equivalents $ 4 $ — $ — $ 4 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 11 — 11 Municipal obligations — 40 — 40 Agency, asset and mortgage-backed obligations — 15 — 15 Equity securities: United States companies 128 — — 128 Investment funds (2) 56 — — 56 Total $ 193 $ 66 $ — $ 259 (1) Refer to Note 13 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 68% and 32% , respectively, for 2015 and 69% and 31% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 32% and 68% , respectively, for 2015 and 31% and 69% , respectively, for 2014 . 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. When observable market data is not available, the fair value is determined using unobservable inputs, such as estimated future cash flows, purchase multiples paid in other comparable third-party transactions or other information. The real estate funds determine fair value of their underlying assets using independent appraisals given there is no current liquid market for the underlying assets. The following table reconciles the beginning and ending balances of MidAmerican Energy's pension plan assets measured at fair value using significant Level 3 inputs for the years ended December 31, (in millions): Real Estate Funds 2015 2014 2013 Beginning balance $ 40 $ 31 $ 26 Actual return on plan assets still held at period end 7 4 5 Purchases and sales — 5 — Ending balance $ 47 $ 40 $ 31 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 , $19 million , and $17 million for the years ended December 31, 2015 , 2014 and 2013 , respectively.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Defined Benefit Plan Disclosure [Line Items]
Employee Benefit Plans [Text Block]	Employee Benefit Plans Refer to Note 10 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): 2015 2014 2013 Pension costs $ 4 $ 4 $ 6 Other postretirement costs (2 ) (2 ) (2 )

Retirement Plan and Postretirem

Retirement Plan and Postretirement Benefits Retirement Plan and Postretirement Benefits (Notes)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 2015 2014 2013 Service cost $ 33 $ 36 $ 24 $ 11 $ 14 $ 14 Interest cost 121 131 87 31 46 33 Expected return on plan assets (169 ) (164 ) (119 ) (45 ) (53 ) (44 ) Net amortization 53 44 58 (11 ) (3 ) 6 Net periodic benefit cost (credit) $ 38 $ 47 $ 50 $ (14 ) $ 4 $ 9 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 2015 2014 2015 2014 Plan assets at fair value, beginning of year $ 2,718 $ 2,711 $ 858 $ 852 Employer contributions 13 37 2 2 Participant contributions — — 9 11 Actual return on plan assets (17 ) 188 — 54 Settlement (23 ) — (150 ) — Benefits paid (202 ) (218 ) (57 ) (61 ) Plan assets at fair value, end of year $ 2,489 $ 2,718 $ 662 $ 858 The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions): Pension Other Postretirement 2015 2014 2015 2014 Benefit obligation, beginning of year $ 3,119 $ 2,821 $ 936 $ 987 Service cost 33 36 11 14 Interest cost 121 131 31 46 Participant contributions — — 9 11 Actuarial loss (gain) (110 ) 349 (43 ) (61 ) Amendment (4 ) — 3 — Settlement (23 ) — (150 ) — Benefits paid (202 ) (218 ) (57 ) (61 ) Benefit obligation, end of year $ 2,934 $ 3,119 $ 740 $ 936 Accumulated benefit obligation, end of year $ 2,906 $ 3,086 In conjunction with the Utah Mine Disposition described in Note 6 , 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 actuarial gain associated with the other postretirement benefit obligation during the year ended December 31, 2014 includes a gain that reduced the benefit obligation associated with the UMWA plan participants to $150 million . 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 2015 2014 2015 2014 Plan assets at fair value, end of year $ 2,489 $ 2,718 $ 662 $ 858 Benefit obligation, end of year 2,934 3,119 740 936 Funded status $ (445 ) $ (401 ) $ (78 ) $ (78 ) Amounts recognized on the Consolidated Balance Sheets: Other assets $ 7 $ 12 $ 15 $ 10 Other current liabilities (15 ) (14 ) — — Other long-term liabilities (437 ) (399 ) (93 ) (88 ) Amounts recognized $ (445 ) $ (401 ) $ (78 ) $ (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 $228 million and $247 million as of December 31, 2015 and 2014 , 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 2015 2014 2015 2014 Fair value of plan assets $ 1,811 $ 1,987 $ 413 $ 598 Projected benefit obligation $ 2,263 $ 2,401 $ 505 $ 686 Accumulated benefit obligation $ 2,244 $ 2,380 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 2015 2014 2015 2014 Net loss $ 768 $ 757 $ 97 $ 108 Prior service credit (25 ) (31 ) (68 ) (87 ) Regulatory deferrals (2 ) (3 ) 8 2 Total $ 741 $ 723 $ 37 $ 23 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2015 and 2014 is as follows (in millions): Accumulated Other Regulatory Regulatory Comprehensive Asset Liability Loss Total Pension Balance, December 31, 2013 $ 490 $ (58 ) $ 9 $ 441 Net loss arising during the year 258 52 16 326 Net amortization (38 ) — (6 ) (44 ) Total 220 52 10 282 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 Regulatory Regulatory Asset Liability Total Other Postretirement Balance, December 31, 2013 $ 99 $ (16 ) $ 83 Net (gain) loss arising during the year (64 ) 1 (63 ) Net amortization 2 1 3 Total (62 ) 2 (60 ) 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 The net loss, prior service credit and regulatory deferrals that will be amortized in 2016 into net periodic benefit cost are estimated to be as follows (in millions): Net Prior Service Regulatory Loss Credit Deferrals Total Pension $ 58 $ (11 ) $ (1 ) $ 46 Other postretirement 3 (16 ) 1 (12 ) Total $ 61 $ (27 ) $ — $ 34 Plan Assumptions Weighted-average assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2015 2014 2013 2015 2014 2013 Benefit obligations as of December 31: Discount rate 4.43 % 4.00 % 4.81 % 4.33 % 3.88 % 4.82 % Rate of compensation increase 2.75 % 2.75 % 3.00 % N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.00 % 4.81 % 4.03 % 3.93 % 4.82 % 4.01 % Expected return on plan assets 6.88 % 6.86 % 7.50 % 7.00 % 7.34 % 7.44 % Rate of compensation increase 2.75 % 3.00 % 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. 2015 2014 Assumed healthcare cost trend rates as of December 31: Healthcare cost trend rate assumed for next year 7.70 % 8.00 % 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, 2015 $ 1 $ (1 ) Other postretirement benefit obligation as of December 31, 2015 5 (5 ) Contributions and Benefit Payments Employer contributions to the pension and other postretirement benefit plans are expected to be $34 million and $1 million , respectively, during 2016 . 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 2016 through 2020 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Other Pension Postretirement 2016 $ 221 $ 56 2017 224 57 2018 226 58 2019 224 58 2020 225 61 2021-2025 1,054 272 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, 2015 : 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 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, 2015 Cash equivalents $ — $ 31 $ — $ 31 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) 144 821 — 965 Limited partnership interests (3) — — 65 65 Real estate funds — — 47 47 Total $ 1,007 $ 1,370 $ 112 $ 2,489 As of December 31, 2014 Cash equivalents $ 15 $ 54 $ — $ 69 Debt securities: United States government obligations 166 — — 166 International government obligations — 11 — 11 Corporate obligations — 268 — 268 Municipal obligations — 27 — 27 Agency, asset and mortgage-backed obligations — 94 — 94 Equity securities: United States companies 698 — — 698 International companies 122 — — 122 Investment funds (2) 301 852 — 1,153 Limited partnership interests (3) — — 70 70 Real estate funds — — 40 40 Total $ 1,302 $ 1,306 $ 110 $ 2,718 (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 66% and 34% , respectively, for 2015 and 61% and 39% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 58% and 42% , respectively, for 2015 and 64% and 36% , respectively, for 2014 . (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, 2015 Cash equivalents (2) $ 12 $ 2 $ — $ 14 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 (3) 149 153 — 302 Limited partnership interests (4) — — 4 4 Total $ 401 $ 257 $ 4 $ 662 As of December 31, 2014 Cash equivalents $ 145 $ 1 $ — $ 146 Debt securities: United States government obligations 17 — — 17 Corporate obligations — 34 — 34 Municipal obligations — 43 — 43 Agency, asset and mortgage-backed obligations — 31 — 31 Equity securities: United States companies 243 — — 243 International companies 6 — — 6 Investment funds (3) 202 131 — 333 Limited partnership interests (4) — — 5 5 Total $ 613 $ 240 $ 5 $ 858 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) In December 2014, PacifiCorp began to migrate funds to cash and cash equivalents in anticipation of the $150 million to be transferred to a fund managed by the UMWA in May 2015 as a result of the other postretirement settlement. Remaining investments were rebalanced to align to PacifiCorp's target investment allocations. (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 2015 and 63% and 37% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 70% and 30% , respectively, for 2015 and 69% and 31% , respectively, for 2014 . (4) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. 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. When observable market data is not available, the fair value is determined using unobservable inputs, such as estimated future cash flows, purchase multiples paid in other comparable third-party transactions or other information. Investments in limited partnerships are valued at estimated fair value based on the Plan's proportionate share of the partnerships' fair value as recorded in the partnerships' most recently available financial statements adjusted for recent activity and forecasted returns. The fair values recorded in the partnerships' financial statements are generally determined based on closing public market prices for publicly traded securities and as determined by the general partners for other investments based on factors including estimated future cash flows, purchase multiples paid in other comparable third-party transactions, comparable public company trading multiples and other information. The real estate funds determine fair value of their underlying assets using independent appraisals given there is no current liquid market for the underlying assets. The following table reconciles the beginning and ending balances of the Company's plan assets measured at fair value using significant Level 3 inputs for the years ended December 31 (in millions): Other Pension Postretirement- Limited Real Limited Partnership Estate Partnership Interests Funds Interests Balance, December 31, 2012 $ 96 $ 26 $ 7 Actual return on plan assets still held at period end 16 5 1 Purchases, sales, distributions and settlements (26 ) — (2 ) Balance, December 31, 2013 86 31 6 Actual return on plan assets still held at period end (1 ) 4 — Purchases, sales, distributions and settlements (15 ) 5 (1 ) Balance, December 31, 2014 70 40 5 Actual return on plan assets still held at period end 5 7 — Purchases, sales, distributions and settlements (10 ) — (1 ) Balance, December 31, 2015 $ 65 $ 47 $ 4 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): 2015 2014 2013 Service cost $ 24 $ 24 $ 22 Interest cost 79 95 85 Expected return on plan assets (116 ) (124 ) (101 ) Net amortization 62 51 53 Net periodic benefit cost $ 49 $ 46 $ 59 Funded Status The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions): 2015 2014 Plan assets at fair value, beginning of year $ 2,368 $ 2,177 Employer contributions 77 89 Participant contributions 2 2 Actual return on plan assets 48 337 Benefits paid (91 ) (92 ) Foreign currency exchange rate changes (128 ) (145 ) Plan assets at fair value, end of year $ 2,276 $ 2,368 The following table is a reconciliation of the benefit obligation for the years ended December 31 (in millions): 2015 2014 Benefit obligation, beginning of year $ 2,279 $ 2,185 Service cost 24 24 Interest cost 79 95 Participant contributions 2 2 Actuarial (gain) loss (30 ) 205 Benefits paid (91 ) (92 ) Foreign currency exchange rate changes (121 ) (140 ) Benefit obligation, end of year $ 2,142 $ 2,279 Accumulated benefit obligation, end of year $ 1,891 $ 2,019 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): 2015 2014 Plan assets at fair value, end of year $ 2,276 $ 2,368 Benefit obligation, end of year 2,142 2,279 Funded status $ 134 $ 89 Amounts recognized on the Consolidated Balance Sheets: Other assets $ 134 $ 89 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): 2015 2014 Net loss $ 592 $ 655 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): 2015 2014 Balance, beginning of year $ 655 $ 751 Net loss (gain) arising during the year 38 (8 ) Net amortization (62 ) (51 ) Foreign currency exchange rate changes (39 ) (37 ) Total (63 ) (96 ) Balance, end of year $ 592 $ 655 The net loss that will be amortized from accumulated other comprehensive loss in 2016 into net periodic benefit cost is estimated to be $48 million . Plan Assumptions Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: 2015 2014 2013 Benefit obligations as of December 31: Discount rate 3.70 % 3.60 % 4.40 % Rate of compensation increase 2.90 % 2.80 % 3.15 % Rate of future price inflation 2.90 % 2.80 % 3.15 % Net periodic benefit cost for the years ended December 31: Discount rate 3.60 % 4.40 % 4.40 % Expected return on plan assets 5.60 % 6.10 % 5.70 % Rate of compensation increase 2.80 % 3.15 % 2.80 % Rate of future price inflation 2.80 % 3.15 % 2.80 % Contributions and Benefit Payments Employer contributions to the UK Plan are expected to be £40 million during 2016 . The expected benefit payments to participants in the UK Plan for 2016 through 2020 and for the five years thereafter, using the foreign currency exchange rate as of December 31, 2015 , are summarized below (in millions): 2016 $ 88 2017 90 2018 92 2019 95 2020 97 2021-2025 522 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, 2015 : % 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 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, 2015 Cash equivalents $ 46 $ — $ — $ 46 Debt securities: United Kingdom government obligations 424 — — 424 Other international government obligations — 13 — 13 Corporate obligations — 186 — 186 Investment funds (2) 109 1,294 — 1,403 Real estate funds — — 204 204 Total $ 579 $ 1,493 $ 204 $ 2,276 As of December 31, 2014 Cash equivalents $ 43 $ — $ — $ 43 Debt securities: United States government obligations — — — — United Kingdom government obligations 452 — — 452 Other international government obligations — 14 — 14 Corporate obligations — 196 — 196 Investment funds (2) 114 1,350 — 1,464 Real estate funds — — 199 199 Total $ 609 $ 1,560 $ 199 $ 2,368 (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% for both 2015 and 2014 . 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 2015 2014 2013 Beginning balance $ 199 $ 179 $ 163 Actual return on plan assets still held at period end 18 33 12 Foreign currency exchange rate changes (13 ) (13 ) 4 Ending balance $ 204 $ 199 $ 179 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 $90 million , $83 million and $63 million for the years ended December 31, 2015 , 2014 and 2013 , 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 did not make any contributions to the Qualified Pension Plan, Non‑Qualified Pension Plans or Other Postretirement Plans for the years ended December 31 , 2015 , 2014 and 2013 . 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): 2015 2014 Qualified Pension Plan - Other long-term liabilities $ (38 ) $ (23 ) Non-Qualified Pension Plans: Other current liabilities (1 ) (1 ) Other long-term liabilities (9 ) (9 ) Other Postretirement Plans - Other long-term liabilities (5 ) 1
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 $20 million to the Qualified Pension Plan for the year ended December 31 , 2013 , and did not make a contribution in 2014 and 2015 . For the Other Postretirement Plans, Sierra Pacific contributed $5 million for the year ended December 31 , 2013 , and did not make a contribution in 2014 and 2015 . Sierra Pacific did not make any contributions to the Non-Qualified Pension Plans for the years ended December 31 , 2015 , 2014 and 2013 . 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): 2015 2014 Qualified Pension Plan - Other long-term liabilities $ (29 ) $ (13 ) Non-Qualified Pension Plans: Other current liabilities (1 ) (1 ) Other long-term liabilities (9 ) (10 ) Other Postretirement Plans - Other long-term liabilities (32 ) (33 )

Asset Retirement Obligations (N

Asset Retirement Obligations (Notes)	12 Months Ended
	Dec. 31, 2015
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, 2015 and 2014 , respectively. The following table presents the Company's ARO liabilities by asset type as of December 31 (in millions): 2015 2014 Fossil fuel facilities $ 443 $ 334 Quad Cities Station 289 265 Wind generating facilities 104 75 Offshore pipeline facilities 31 31 Solar generating facilities 12 9 Other 42 39 Total asset retirement obligations $ 921 $ 753 Quad Cities Station nuclear decommissioning trust funds $ 429 $ 424 The following table reconciles the beginning and ending balances of the Company's ARO liabilities for the years ended December 31 (in millions): 2015 2014 Beginning balance $ 753 $ 696 Acquisitions — 12 Change in estimated costs 104 3 Additions 59 15 Retirements (32 ) (8 ) Accretion 37 35 Ending balance $ 921 $ 753 Reflected as: Other current liabilities $ 92 $ 66 Other long-term liabilities 829 687 Total ARO liability $ 921 $ 753 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. The decommissioning costs are included in base rates in MidAmerican Energy's Iowa tariffs. 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 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 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 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 $894 million and $873 million as of December 31, 2015 and 2014 , respectively. The following table reconciles the beginning and ending balances of PacifiCorp's ARO liabilities for the years ended December 31 (in millions): 2015 2014 Beginning balance $ 135 $ 138 Change in estimated costs 62 (3 ) Additions 30 — Retirements (10 ) (6 ) Accretion 7 6 Ending balance $ 224 $ 135 Reflected as: Other current liabilities $ 35 $ 21 Other long-term liabilities 189 114 $ 224 $ 135 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 $653 million and $642 million as of December 31, 2015 and 2014 , respectively. The following table presents MidAmerican Energy's ARO liabilities by asset type as of December 31, (in millions): 2015 2014 Quad Cities Station $ 289 $ 265 Fossil-fueled generating facilities 160 132 Wind-powered generating facilities 82 60 Other 1 3 Total asset retirement obligations $ 532 $ 460 Quad Cities Station nuclear decommissioning trust funds (1) $ 429 $ 424 (1) Refer to Note 6 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): 2015 2014 Beginning balance $ 460 $ 430 Change in estimated costs 36 (2 ) Additions 22 11 Retirements (9 ) — Accretion 23 21 Ending balance $ 532 $ 460 Reflected as: Other current liabilities $ 44 $ 28 Asset retirement obligations 488 432 $ 532 $ 460 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, which was effective in October 2015, resulted in increases to MidAmerican Energy's ARO liabilities due to changes in the expected timing and amount of cash flow for ash pond closures at some of MidAmerican Energy's thermal generating facilities.
MidAmerican Funding, LLC and Subsidiaries [Domain]
Asset Retirement Obligations Disclosure [Line Items]
Asset Retirement Obligations [Text Block]	Asset Retirement Obligations Refer to Note 11 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 $273 million and $295 million as of December 31 , 2015 and 2014 , respectively. The following table presents Nevada Power 's ARO liabilities by asset type as of December 31 (in millions): 2015 2014 Waste water remediation $ 42 $ 53 Evaporative ponds and dry ash landfills 27 25 Asbestos 3 3 Other 13 5 Total asset retirement obligations $ 85 $ 86 The following table reconciles the beginning and ending balances of Nevada Power 's ARO liabilities for the years ended December 31 (in millions): 2015 2014 Beginning balance $ 86 $ 100 Change in estimated costs 3 (18 ) Additions 3 — Retirements (11 ) — Accretion 4 4 Ending balance $ 85 $ 86 Reflected as: Other current liabilities $ 13 $ 14 Other long-term liabilities 72 72 $ 85 $ 86 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. The 2014 change in estimated costs was related to refinement of expected remediation costs at the Reid Gardner Generating Station and impacts of the new coal combustion rule. 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 $208 million and $233 million as of December 31 , 2015 and 2014 , respectively. The following table presents Sierra Pacific 's ARO liabilities by asset type as of December 31 (in millions): 2015 2014 Asbestos $ 4 $ 5 Evaporative ponds and dry ash landfills 3 2 Other 3 4 Total asset retirement obligations $ 10 $ 11 The following table reconciles the beginning and ending balances of Sierra Pacific 's ARO liabilities for the years ended December 31 (in millions): 2015 2014 Beginning balance $ 11 $ 16 Change in estimated costs — (6 ) Retirements (1 ) — Accretion — 1 Ending balance $ 10 $ 11 Reflected as: Other current liabilities $ — $ 3 Other long-term liabilities 10 8 $ 10 $ 11 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. The impact of this new rule is reflected in the December 31 , 2015 change in estimated costs above.

Commitments and Contingencies (

Commitments and Contingencies (Notes)	12 Months Ended
	Dec. 31, 2015
Contractual Obligation [Line Items]
Commitments and Contingencies	Commitments and Contingencies 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. 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. USA Power In October 2005, prior to BHE 's ownership of PacifiCorp, PacifiCorp was added as a defendant to a lawsuit originally filed in February 2005 in the Third District Court of Salt Lake County, Utah ("Third District Court") by USA Power, LLC, USA Power Partners, LLC and Spring Canyon Energy, LLC (collectively, the "Plaintiff"). The Plaintiff's complaint alleged that PacifiCorp misappropriated confidential proprietary information in violation of Utah's Uniform Trade Secrets Act and accused PacifiCorp of breach of contract and related claims in regard to the Plaintiff's 2002 and 2003 proposals to build a natural gas-fueled generating facility in Juab County, Utah. In October 2007, the Third District Court granted PacifiCorp's motion for summary judgment on all counts and dismissed the Plaintiff's claims in their entirety. In a May 2010 ruling on the Plaintiff's petition for reconsideration, the Utah Supreme Court reversed summary judgment and remanded the case back to the Third District Court for further consideration. In May 2012, a jury awarded damages to the Plaintiff for breach of contract and misappropriation of a trade secret in the amounts of $18 million for actual damages and $113 million for unjust enrichment. After considering various motions filed by the parties to expand or limit damages, interest and attorney's fees, in May 2013, the court entered a final judgment against PacifiCorp in the amount of $115 million , which includes the $113 million of aggregate damages previously awarded and amounts awarded for the Plaintiff's attorneys' fees. The final judgment also ordered that postjudgment interest accrue beginning as of the date of the April 2013 initial judgment. In May 2013, PacifiCorp posted a surety bond issued by a subsidiary of Berkshire Hathaway to secure its estimated obligation. PacifiCorp strongly disagrees with the jury's verdict and is vigorously pursuing all appellate measures. Both PacifiCorp and the Plaintiff filed appeals with the Utah Supreme Court. Briefing before the Utah Supreme Court is complete and oral arguments were heard in September 2015. As of December 31, 2015 , PacifiCorp had accrued $122 million for the final judgment and postjudgment interest, and believes the likelihood of any additional material loss is remote; however, any additional awards against PacifiCorp could also have a material effect on the consolidated financial results. Any payment of damages will be at the end of the appeals process. Commitments The Company has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31, 2015 are as follows (in millions): 2021 and 2016 2017 2018 2019 2020 Thereafter Total Contract type: Fuel, capacity and transmission contract commitments $ 2,214 $ 1,760 $ 1,345 $ 1,229 $ 1,129 $ 9,494 $ 17,171 Construction commitments 1,544 25 11 3 3 5 1,591 Operating leases and easements 143 118 95 77 66 1,007 1,506 Maintenance, service and other contracts 181 264 180 188 156 805 1,774 $ 4,082 $ 2,167 $ 1,631 $ 1,497 $ 1,354 $ 11,311 $ 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, 2015 , 2014 and 2013 , $185 million , $159 million and $174 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: • BHE Renewables' construction of certain assets that will facilitate the development of up to 472 MW of wind-powered generating facilities in Nebraska and Kansas. • MidAmerican Energy's construction of wind-powered generating facilities in 2016 and four Multi-Value Projects approved by the Midcontinent Independent System Operator, Inc. for high voltage transmission lines in Iowa and Illinois in 2016 and 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 $161 million for 2015 , $146 million for 2014 and $118 million for 2013 . 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. 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 the Company's 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 provides that the United States Department of the Interior conduct scientific and engineering studies to assess whether removal of the Klamath hydroelectric system's mainstem dams is in the public interest and will advance restoration of the Klamath Basin's salmonid fisheries. If it is determined that dam removal should proceed, dam removal is expected to begin no earlier than 2020. Under the KHSA, PacifiCorp and its customers are protected from uncapped dam removal costs and liabilities. For dam removal to occur, federal legislation consistent with the KHSA is required to provide, among other things, protection for PacifiCorp from all liabilities associated with dam removal activities. As of December 31, 2015, no federal legislation was enacted. 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. Any amendment to the KHSA would ensure that the existing KHSA framework would remain in place, capping PacifiCorp's costs and requiring transfer of the dams to a separate entity that would remove the dams and provide PacifiCorp and its customers with protections against potential dam removal liabilities. If the KHSA is not amended, then PacifiCorp will resume relicensing with the FERC. The KHSA limits PacifiCorp's contribution to dam 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. Additional funding of up to $250 million for dam removal costs is to be provided by the state of California. California voters approved a water bond measure in November 2014 from which the state of California's contribution towards dam removal costs will be drawn. If dam 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 an entity other than PacifiCorp in order for the KHSA and dam removal to proceed. PacifiCorp has begun collection of surcharges from Oregon and California customers for their share of dam removal costs, as approved by the OPUC and the CPUC, and is depositing the proceeds into trust accounts maintained by the OPUC and the CPUC, respectively. PacifiCorp is authorized to collect the surcharges through 2019. As of December 31, 2015 , PacifiCorp's assets included $81 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 $252 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. PacifiCorp 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. USA Power In October 2005, prior to BHE's ownership of PacifiCorp, PacifiCorp was added as a defendant to a lawsuit originally filed in February 2005 in the Third District Court of Salt Lake County, Utah ("Third District Court") by USA Power, LLC, USA Power Partners, LLC and Spring Canyon Energy, LLC (collectively, the "Plaintiff"). The Plaintiff's complaint alleged that PacifiCorp misappropriated confidential proprietary information in violation of Utah's Uniform Trade Secrets Act and accused PacifiCorp of breach of contract and related claims in regard to the Plaintiff's 2002 and 2003 proposals to build a natural gas-fueled generating facility in Juab County, Utah. In October 2007, the Third District Court granted PacifiCorp's motion for summary judgment on all counts and dismissed the Plaintiff's claims in their entirety. In a May 2010 ruling on the Plaintiff's petition for reconsideration, the Utah Supreme Court reversed summary judgment and remanded the case back to the Third District Court for further consideration. In May 2012, a jury awarded damages to the Plaintiff for breach of contract and misappropriation of a trade secret in the amounts of $18 million for actual damages and $113 million for unjust enrichment. After considering various motions filed by the parties to expand or limit damages, interest and attorney's fees, in May 2013, the court entered a final judgment against PacifiCorp in the amount of $115 million , which includes the $113 million of aggregate damages previously awarded and amounts awarded for the Plaintiff's attorneys' fees. The final judgment also ordered that postjudgment interest accrue beginning as of the date of the April 2013 initial judgment. In May 2013, PacifiCorp posted a surety bond issued by a subsidiary of Berkshire Hathaway to secure its estimated obligation. PacifiCorp strongly disagrees with the jury's verdict and is vigorously pursuing all appellate measures. Both PacifiCorp and the Plaintiff filed appeals with the Utah Supreme Court. Briefing before the Utah Supreme Court is complete and oral arguments were heard in September 2015. As of December 31, 2015 , PacifiCorp had accrued $122 million for the final judgment and postjudgment interest, and believes the likelihood of any additional material loss is remote; however, any additional awards against PacifiCorp could also have a material effect on the consolidated financial results. Any payment of damages will be at the end of the appeals process. Sanpete County, Utah Rangeland Fire In June 2012, a major rangeland fire occurred in Sanpete County, Utah. Certain parties allege that contact between two of PacifiCorp's transmission lines may have triggered a ground fault that led to the fire. PacifiCorp has engaged experts to review the cause and origin of the fire, as well as to assess the damages. PacifiCorp has accrued its best estimate of the potential loss and expected insurance recovery. PacifiCorp believes it is reasonably possible it may incur additional loss beyond the amount accrued, but does not believe the potential additional loss 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 provides that the United States Department of the Interior conduct scientific and engineering studies to assess whether removal of the Klamath hydroelectric system's mainstem dams is in the public interest and will advance restoration of the Klamath Basin's salmonid fisheries. If it is determined that dam removal should proceed, dam removal is expected to begin no earlier than 2020. Under the KHSA, PacifiCorp and its customers are protected from uncapped dam removal costs and liabilities. For dam removal to occur, federal legislation consistent with the KHSA is required to provide, among other things, protection for PacifiCorp from all liabilities associated with dam removal activities. As of December 31, 2015, no federal legislation was enacted. 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. Any amendment to the KHSA would ensure that the existing KHSA framework would remain in place, capping PacifiCorp's costs and requiring transfer of the dams to a separate entity that would remove the dams and provide PacifiCorp and its customers with protections against potential dam removal liabilities. If the KHSA is not amended, then PacifiCorp will resume relicensing with the FERC. The KHSA limits PacifiCorp's contribution to dam 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. Additional funding of up to $250 million for dam removal costs is to be provided by the state of California. California voters approved a water bond measure in November 2014 from which the state of California's contribution towards dam removal costs will be drawn. If dam 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 an entity other than PacifiCorp in order for the KHSA and dam removal to proceed. PacifiCorp has begun collection of surcharges from Oregon and California customers for their share of dam removal costs, as approved by the OPUC and the CPUC, and is depositing the proceeds into trust accounts maintained by the OPUC and the CPUC, respectively. PacifiCorp is authorized to collect the surcharges through 2019. As of December 31, 2015 , PacifiCorp's assets included $81 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 $252 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, 2015 are as follows (in millions): 2016 2017 2018 2019 2020 2021 and Thereafter Total Contract type: Purchased electricity contracts - commercially operable $ 168 $ 71 $ 70 $ 67 $ 68 $ 401 $ 845 Purchased electricity contracts - non-commercially operable 16 102 104 104 104 1,687 2,117 Fuel contracts 862 689 558 542 496 1,720 4,867 Construction commitments 144 12 10 2 2 5 175 Transmission 105 97 91 76 55 508 932 Operating leases and easements 5 4 4 4 4 42 63 Maintenance, service and other contracts 36 30 19 24 11 74 194 Total commitments $ 1,336 $ 1,005 $ 856 $ 819 $ 740 $ 4,437 $ 9,193 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 $13 million for 2015 , $15 million for 2014 and $24 million for 2013 . 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 2015 , 2014 and 2013 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 year ended December 31, 2015 and $16 million for each of the years ended December 31, 2014 and 2013 . 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, 2015 , are as follows (in millions): 2021 and 2016 2017 2018 2019 2020 Thereafter Total Contract type: Coal and natural gas for generation $ 173 $ 113 $ 72 $ 29 $ — $ — $ 387 Electric capacity and transmission 30 30 11 10 10 58 149 Natural gas contracts for gas operations 131 69 31 11 10 30 282 Construction commitments 535 10 — — — — 545 Easements and operating leases 17 17 17 16 15 516 598 Maintenance and services contracts 47 59 71 73 73 265 588 $ 933 $ 298 $ 202 $ 139 $ 108 $ 869 $ 2,549 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 2020 . 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 2016 and the construction in 2016 through 2017 of four 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 $6 million for 2015 , 2014 and 2013 , 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 2029 . 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. 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 14 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. In June 2013, the Nevada State Legislature passed Senate Bill No. 123 ("SB 123"), which included, in significant part: • Accelerating the plan to retire 800 MWs of coal plants, starting as soon as December 31, 2014; • Replacement of such coal plants by issuing requests for proposals for the procurement of 300 MWs from renewable facilities; • Construction or acquisition and ownership of 50 MWs of electric generating capacity from renewable facilities; • Construction or acquisition and ownership of 550 MWs of additional electric generating capacity; and • Assuring regulatory procedures that protect reliability and supply and address financial impacts on customer and utility. In May 2014, Nevada Power filed its Emissions Reduction Capacity Replacement Plan ("ERCR Plan") in compliance with SB 123. The filing proposed, among other items, the retirement of Reid Gardner Generating Station units 1, 2 and 3 in 2014 and unit 4 in 2017; the elimination of Nevada Power 's ownership interest in Navajo Generating Station in 2019; and a plan to replace the generating capacity being retired, as required by SB 123. The ERCR Plan includes the issuance of requests for proposals for 300 MW of renewable energy to be issued between 2014 and 2016; the acquisition of a 272 -MW natural gas co-generating facility in 2014; the acquisition of a 210 -MW natural gas peaking facility in 2014; the construction of a 15 -MW solar photovoltaic facility expected to be placed in-service in 2015; and the construction of a 200 -MW solar photovoltaic facility expected to be placed in-service in 2016. In the second quarter of 2014, Nevada Power executed various contractual agreements to fulfill the proposed ERCR Plan, which are subject to the PUCN approval. The PUCN issued an order dated October 28, 2014 removing the 200 -MW solar photovoltaic facility proposed by Nevada Power from the ERCR Plan but accepting the remaining requests. In November 2014, Nevada Power filed a petition for reconsideration, but in December 2014, the PUCN upheld the original order from October 2014 with respect to material matters. In December 2014, Nevada Power filed its acceptance of the modifications to the ERCR Plan. In July 2015, Nevada Power filed an amendment to its Emissions Reduction and Capacity Replacement Plan ("ERCR Plan") with the PUCN. In September 2015, the PUCN approved the filed amendment requesting two renewable power purchase agreements with 100 ‑MW solar photovoltaic generating facilities related to the replacement of coal plants. Each of these agreements were entered into by issuing requests for proposals for the procurement of energy through the competitive solicitation process that was set forth in Nevada Power's ERCR Plan in compliance with SB 123. In June 2015, the Nevada State Legislature passed Assembly Bill No. 498, which modified the capacity replacement components of SB 123. As a result, Nevada Power will not proceed with issuance of a third 100 -MW request for proposal for renewable energy until such time as the PUCN determines Nevada Power has satisfactorily demonstrated a need for such electric generating capacity. 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. Commitments Nevada Power has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31 , 2015 are as follows (in millions): 2016 2017 2018 2019 2020 2021 and Thereafter Total Contract type: Fuel and capacity contract commitments $ 612 $ 478 $ 330 $ 328 $ 330 $ 4,587 $ 6,665 Fuel and capacity contract commitments (not commercially operable) — 20 23 23 30 603 699 Operating leases and easements 11 8 8 7 7 67 108 Maintenance, service and other contracts 46 116 38 37 35 109 381 Total commitments $ 669 $ 622 $ 399 $ 395 $ 402 $ 5,366 $ 7,853 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 2040 . Purchased power includes contracts which meet the definition of a lease. Nevada Power 's rent expense for purchase power contracts which met the lease criteria for 2015 , 2014 and 2013 were $264 million , $245 million and $400 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 2016 to 2031 and the gas supply contract expires in 2017 . 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. Rent expense on non-cancelable operating leases totaled $11 million , $10 million and $9 million for the years ended December 31 , 2015 , 2014 and 2013 , 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 2020 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 , 2015 are as follows (in millions): 2021 and 2016 2017 2018 2019 2020 Thereafter Total Contract type: Fuel and capacity contract commitments $ 207 $ 159 $ 109 $ 88 $ 75 $ 444 $ 1,082 Operating leases and easements 6 4 3 3 3 65 84 Maintenance, service and other contracts 5 4 4 5 5 22 45 Total commitments $ 218 $ 167 $ 116 $ 96 $ 83 $ 531 $ 1,211 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 2016 to 2039 . Purchased power includes contracts which meet the definition of a lease. Sierra Pacific 's rent expense for purchase power contracts which met the lease criteria for 2015 , 2014 and 2013 were $65 million , $68 million and $63 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 2016 to 2018 . Additionally, gas transportation contracts expire from 2017 to 2046 and the gas supply contracts expire from 2016 to 2017 . 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. Rent expense on non-cancelable operating leases totaled $7 million , $6 million and $5 million for the year-ended December 31 , 2015 , 2014 and 2013 , 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 2023 to 2039 .

Preferred Stock (Notes)

Preferred Stock (Notes)	12 Months Ended
	Dec. 31, 2015
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, 2015 and 2014 . The outstanding preferred stock series are non-redeemable and have annual dividend rates of 6.00% and 7.00% . In 2013, PacifiCorp redeemed and canceled all outstanding shares of its redeemable preferred stock at stated redemption prices, which in aggregate totaled $40 million , plus accrued and unpaid dividends. 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, 2015 and 2014 .
MidAmerican Energy Company [Member]
Class of Stock [Line Items]
Preferred Stock [Text Block]	Preferred Securities In April 2013, MidAmerican Energy redeemed and canceled all outstanding shares of each series of its preferred securities at the stated redemption prices, which in aggregate totaled $28 million including accrued dividends.

BHE Shareholders' Equity (Notes

BHE Shareholders' Equity (Notes)	12 Months Ended
	Dec. 31, 2015
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 December 19, 2013, Berkshire Hathaway and other existing shareholders invested $1.0 billion , in the aggregate, in 2,857,143 shares of BHE 's common stock in order to provide equity funding for the NV Energy Transaction (see Note 3 ). The per-share value assigned to the shares of common stock issued, which were effected pursuant to a private placement and were exempt from the registration requirements of the Securities Act of 1933, as amended, was based on a per share value as agreed to by BHE 's shareholders. 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 2017 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 $12.7 billion as of December 31, 2015 . 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 $17.2 billion as of December 31, 2015 .

Common Shareholder's Equity Com

Common Shareholder's Equity Common Shareholder's Equity (Notes)	12 Months Ended
	Dec. 31, 2015
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 December 19, 2013, Berkshire Hathaway and other existing shareholders invested $1.0 billion , in the aggregate, in 2,857,143 shares of BHE 's common stock in order to provide equity funding for the NV Energy Transaction (see Note 3 ). The per-share value assigned to the shares of common stock issued, which were effected pursuant to a private placement and were exempt from the registration requirements of the Securities Act of 1933, as amended, was based on a per share value as agreed to by BHE 's shareholders. 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 2017 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 $12.7 billion as of December 31, 2015 . 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 $17.2 billion as of December 31, 2015 .
PacifiCorp [Member]
Class of Stock [Line Items]
Common Shareholder's Equity [Text Block]	Common Shareholder's Equity In February 2016, 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 2016. 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, 2015 , 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, 2015 , PacifiCorp's actual common equity percentage, as calculated under this measure, was 52% , and PacifiCorp would have been permitted to dividend $2.0 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, 2015 , 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, 2015
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, 2012 $ (575 ) $ (172 ) $ 261 $ 23 $ (463 ) Other comprehensive income 16 74 263 13 366 Balance, December 31, 2013 (559 ) (98 ) 524 36 (97 ) Other comprehensive income (loss) 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 ) Reclassifications from AOCI to net income for the years ended December 31, 2015 , 2014 and 2013 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 $11 million and $13 million as of December 31, 2015 and 2014 , 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, 2015 and 2014 (in millions): Unrealized Unrealized Accumulated Losses on Losses Other Available-For-Sale on Cash Flow Comprehensive Securities Hedges Loss, Net Balance, December 31, 2013 $ (4 ) $ (7 ) $ (11 ) Other comprehensive income (loss) 1 (13 ) (12 ) Balance, December 31, 2014 $ (3 ) $ (20 ) $ (23 ) Other comprehensive income (loss) — (7 ) (7 ) Balance, December 31, 2015 $ (3 ) $ (27 ) $ (30 ) For information regarding cash flow hedge reclassifications from AOCI to net income in their entirety for the years ended December 31, 2015 , 2014 and 2013 , refer to Note 12 .
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 15 of MidAmerican Energy's Notes to Financial Statements.

Variable-Interest Entities Vari

Variable-Interest Entities Variable-Interest Entities (Notes)	12 Months Ended
	Dec. 31, 2015
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), dictates when the generating facility operates, procures 100% of the natural gas for the generating facility and subsequently receives 100% of the generated electricity, 50% of which is acquired through a power purchase agreement that expires on July 1, 2016. As a result, PacifiCorp holds a variable interest in the joint owner of the remaining 50% of the facility and is the primary beneficiary. PacifiCorp has been unable to obtain the information necessary to consolidate the entity because the entity has not agreed to supply the information due to the lack of a contractual obligation to do so. PacifiCorp continues to request from the entity the information necessary to perform the consolidation; however, no information has yet been provided by the entity. Cost of the electricity purchased from the joint owner was $39 million during the year ended December 31, 2015 and $38 million during each of the years ended December 31, 2014 and 2013 . 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 $190 million and $192 million as of December 31, 2015 and 2014 , 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, 2015
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, 2015 and 2014 , 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 at PacifiCorp. In 2013, PacifiCorp redeemed and canceled all outstanding shares of its redeemable preferred stock at stated redemption prices, which in aggregate totaled $40 million , plus accrued and unpaid dividends, and MidAmerican Energy redeemed and canceled all outstanding shares of each series of its preferred securities at the stated redemption prices, which in aggregate totaled $28 million including accrued dividends.
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): 2015 2014 2013 Corporate-owned life insurance income $ 4 $ 8 $ 15 Gains on sales of assets and other investments 13 — 1 Leverage leases 1 5 2 Other, net 1 5 4 Total $ 19 $ 18 $ 22 MidAmerican Funding recognized a $13 million pre-tax gain on the sale of an investment in a generating facility lease in 2015.
Noncontrolling Interests [Text Block]	Noncontrolling Interests Refer to Note 16 of MidAmerican Energy's Notes to Financial Statements for a discussion of MidAmerican Energy's preferred securities, which were MidAmerican Funding's noncontrolling interest at the time of their redemption.

Segment Information (Notes)

Segment Information (Notes)	12 Months Ended
	Dec. 31, 2015
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. Information related to the Company's reportable segments is shown below (in millions): Years Ended December 31, 2015 2014 2013 Operating revenue: PacifiCorp $ 5,232 $ 5,252 $ 5,147 MidAmerican Funding 3,420 3,762 3,413 NV Energy 3,351 3,241 (20 ) Northern Powergrid 1,140 1,283 1,025 BHE Pipeline Group 1,016 1,078 952 BHE Transmission 592 62 — BHE Renewables 728 623 355 HomeServices 2,526 2,144 1,809 BHE and Other (1) (125 ) (119 ) (46 ) Total operating revenue $ 17,880 $ 17,326 $ 12,635 Depreciation and amortization: PacifiCorp $ 780 $ 745 $ 692 MidAmerican Funding 407 351 403 NV Energy 410 379 — Northern Powergrid 202 198 180 BHE Pipeline Group 204 196 190 BHE Transmission 185 13 — BHE Renewables 216 152 71 HomeServices 29 29 33 BHE and Other (1) (5 ) (6 ) (9 ) Total depreciation and amortization $ 2,428 $ 2,057 $ 1,560 Operating income: PacifiCorp $ 1,344 $ 1,308 $ 1,275 MidAmerican Funding 473 423 357 NV Energy 812 791 (42 ) Northern Powergrid 593 674 501 BHE Pipeline Group 464 439 446 BHE Transmission 260 16 (5 ) BHE Renewables 255 314 223 HomeServices 184 125 129 BHE and Other (1) (57 ) (44 ) (49 ) Total operating income 4,328 4,046 2,835 Interest expense (1,904 ) (1,711 ) (1,222 ) Capitalized interest 74 89 84 Allowance for equity funds 91 98 78 Interest and dividend income 107 38 15 Other, net 39 42 51 Total income before income tax expense and equity income (loss) $ 2,735 $ 2,602 $ 1,841 Years Ended December 31, 2015 2014 2013 Interest expense: PacifiCorp $ 383 $ 386 $ 390 MidAmerican Funding 206 197 174 NV Energy 262 283 — Northern Powergrid 145 151 141 BHE Pipeline Group 66 76 80 BHE Transmission 146 14 — BHE Renewables 193 175 138 HomeServices 3 4 3 BHE and Other (1) 500 425 296 Total interest expense $ 1,904 $ 1,711 $ 1,222 Income tax expense (benefit): PacifiCorp $ 328 $ 310 $ 298 MidAmerican Funding (144 ) (110 ) (110 ) NV Energy 207 195 (15 ) Northern Powergrid 35 110 23 BHE Pipeline Group 158 149 149 BHE Transmission 63 28 10 BHE Renewables 41 65 57 HomeServices 72 44 48 BHE and Other (1) (310 ) (202 ) (330 ) Total income tax expense (benefit) $ 450 $ 589 $ 130 Capital expenditures: PacifiCorp $ 916 $ 1,066 $ 1,065 MidAmerican Funding 1,448 1,527 1,027 NV Energy 571 558 — Northern Powergrid 674 675 675 BHE Pipeline Group 240 257 177 BHE Transmission 966 222 — BHE Renewables 1,034 2,221 1,329 HomeServices 16 17 21 BHE and Other 10 12 13 Total capital expenditures $ 5,875 $ 6,555 $ 4,307 As of December 31, 2015 2014 2013 Property, plant and equipment, net: PacifiCorp $ 19,039 $ 18,755 $ 18,563 MidAmerican Funding 11,737 10,535 9,353 NV Energy 9,767 9,648 9,623 Northern Powergrid 5,790 5,599 5,476 BHE Pipeline Group 4,345 4,286 4,147 BHE Transmission 5,301 5,567 — BHE Renewables 4,805 4,897 3,020 HomeServices 70 68 61 BHE and Other (85 ) (107 ) (124 ) Total property, plant and equipment, net $ 60,769 $ 59,248 $ 50,119 Total assets: PacifiCorp $ 23,550 $ 23,404 $ 22,781 MidAmerican Funding 16,499 15,346 13,970 NV Energy 14,656 14,256 14,016 Northern Powergrid 7,317 7,059 6,852 BHE Pipeline Group 4,953 4,951 4,891 BHE Transmission 7,553 7,979 465 BHE Renewables 5,892 6,082 3,832 HomeServices 1,705 1,622 1,375 BHE and Other 1,493 1,117 1,409 Total assets $ 83,618 $ 81,816 $ 69,591 Years Ended December 31, 2015 2014 2013 Operating revenue by country: United States $ 16,121 $ 15,857 $ 11,465 United Kingdom 1,140 1,281 1,023 Canada 600 78 16 Philippines and other 19 110 131 Total operating revenue by country $ 17,880 $ 17,326 $ 12,635 Income before income tax expense and equity income (loss) by country: United States $ 2,034 $ 2,001 $ 1,388 United Kingdom 472 557 373 Canada 165 4 — Philippines and other 64 40 80 Total income before income tax expense and equity income (loss) by country: $ 2,735 $ 2,602 $ 1,841 As of December 31, 2015 2014 2013 Property, plant and equipment, net by country: United States $ 49,680 $ 47,918 $ 44,460 United Kingdom 5,757 5,563 5,439 Canada 5,298 5,570 3 Philippines and other 34 197 217 Total property, plant and equipment, net by country $ 60,769 $ 59,248 $ 50,119 (1) The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other , relate to other corporate entities, 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, 2015 and 2014 (in millions): BHE MidAmerican NV Northern Pipeline BHE BHE Home- PacifiCorp Funding Energy Powergrid Group Transmission Renewables Services Other Total December 31, 2013 $ 1,129 $ 2,102 $ 2,280 $ 1,149 $ 153 $ — $ 15 $ 695 $ 4 $ 7,527 Acquisitions — — 89 — — 1,700 80 66 — 1,935 Foreign currency translation — — — (49 ) — (43 ) — — (1 ) (93 ) Other — — — — (26 ) — — — — (26 ) 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
MidAmerican Energy Company [Member]
Segment Reporting Information [Line Items]
Segment Information [Text Block]	Segment Information MidAmerican Energy has identified three reportable operating segments: regulated electric, regulated gas and nonregulated energy. 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. The nonregulated energy segment derives most of its revenue from nonregulated retail electric and gas activities. 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 9 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, 2015 2014 2013 Operating revenue: Regulated electric $ 1,837 $ 1,817 $ 1,762 Regulated gas 661 996 824 Nonregulated energy 909 927 817 Total operating revenue $ 3,407 $ 3,740 $ 3,403 Depreciation and amortization: Regulated electric $ 366 $ 312 $ 366 Regulated gas 41 39 37 Total depreciation and amortization $ 407 $ 351 $ 403 Operating income: Regulated electric $ 385 $ 319 $ 255 Regulated gas 64 75 74 Nonregulated energy 22 28 27 Total operating income $ 471 $ 422 $ 356 Interest expense: Regulated electric $ 166 $ 157 $ 136 Regulated gas 17 17 15 Total interest expense $ 183 $ 174 $ 151 Income tax (benefit) expense: Regulated electric $ (163 ) $ (138 ) $ (136 ) Regulated gas 16 22 23 Nonregulated energy 6 12 10 Total income tax (benefit) expense $ (141 ) $ (104 ) $ (103 ) Earnings on common stock: Regulated electric $ 413 $ 361 $ 292 Regulated gas 33 40 41 Nonregulated energy 16 16 16 Total earnings on common stock $ 462 $ 417 $ 349 Years Ended December 31, 2015 2014 2013 Utility construction expenditures: Regulated electric $ 1,365 $ 1,429 $ 945 Regulated gas 81 97 81 Total utility construction expenditures $ 1,446 $ 1,526 $ 1,026 As of December 31, 2015 2014 2013 Total assets: Regulated electric $ 12,970 $ 11,850 $ 10,521 Regulated gas 1,251 1,217 1,196 Nonregulated energy 164 167 131 Total assets $ 14,385 $ 13,234 $ 11,848
MidAmerican Funding, LLC and Subsidiaries [Domain]
Segment Reporting Information [Line Items]
Segment Information [Text Block]	Segment Information MidAmerican Funding has identified three reportable operating segments: regulated electric, regulated gas and nonregulated energy. 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. The nonregulated energy segment derives most of its revenue from nonregulated retail electric and gas activities. 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 9 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, 2015 2014 2013 Operating revenue: Regulated electric $ 1,837 $ 1,817 $ 1,762 Regulated gas 661 996 824 Nonregulated energy 910 927 817 Other 12 22 10 Total operating revenue $ 3,420 $ 3,762 $ 3,413 Depreciation and amortization: Regulated electric $ 366 $ 312 $ 366 Regulated gas 41 39 37 Total depreciation and amortization $ 407 $ 351 $ 403 Operating income: Regulated electric $ 385 $ 319 $ 255 Regulated gas 64 75 74 Nonregulated energy 22 28 27 Other 2 1 1 Total operating income $ 473 $ 423 $ 357 Interest expense: Regulated electric $ 166 $ 157 $ 136 Regulated gas 17 17 15 Other 23 23 23 Total interest expense $ 206 $ 197 $ 174 Income tax (benefit) expense: Regulated electric $ (163 ) $ (138 ) $ (136 ) Regulated gas 16 22 23 Nonregulated energy 6 12 10 Other (3 ) (6 ) (7 ) Total income tax (benefit) expense $ (144 ) $ (110 ) $ (110 ) Net income attributable to MidAmerican Funding: Regulated electric $ 413 $ 361 $ 292 Regulated gas 33 40 41 Nonregulated energy 16 16 16 Other (4 ) (8 ) (9 ) Total net income attributable to MidAmerican Funding $ 458 $ 409 $ 340 Utility construction expenditures: Regulated electric $ 1,365 $ 1,429 $ 945 Regulated gas 81 97 81 Total utility construction expenditures $ 1,446 $ 1,526 $ 1,026 As of December 31, 2015 2014 2013 Total assets: Regulated electric $ 14,161 $ 13,041 $ 11,712 Regulated gas 1,330 1,296 1,275 Nonregulated energy 164 167 131 Other 19 18 28 Total assets $ 15,674 $ 14,522 $ 13,146 Goodwill by reportable segment as of December 31, 2015 and 2014 , 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. The following tables provide information on a reportable segment basis for the years ended December 31 (in millions): Years Ended December 31, 2015 2014 2013 Operating revenue: Regulated electric $ 810 $ 779 $ 747 Regulated gas 137 125 106 Total operating revenue $ 947 $ 904 $ 853 Cost of sales: Regulated electric $ 374 $ 361 $ 292 Regulated gas 84 76 56 Total cost of sales $ 458 $ 437 $ 348 Gross margin: Regulated electric $ 436 $ 418 $ 455 Regulated gas 53 49 50 Total gross margin $ 489 $ 467 $ 505 Operating and maintenance: Regulated electric $ 146 $ 140 $ 176 Regulated gas 17 18 21 Total operating and maintenance $ 163 $ 158 $ 197 Depreciation and amortization: Regulated electric $ 96 $ 90 $ 106 Regulated gas 17 15 17 Total depreciation and amortization $ 113 $ 105 $ 123 Operating income: Regulated electric $ 168 $ 165 $ 134 Regulated gas 16 13 6 Total operating income $ 184 $ 178 $ 140 Interest expense: Regulated electric $ 56 $ 57 $ 56 Regulated gas 5 4 5 Total interest expense $ 61 $ 61 $ 61 Income tax expense: Regulated electric $ 43 $ 43 $ 32 Regulated gas 4 4 1 Total income tax expense $ 47 $ 47 $ 33 Years Ended December 31, 2015 2014 2013 Capital expenditures: Regulated electric $ 229 $ 168 $ 125 Regulated gas 23 18 14 Total capital expenditures $ 252 $ 186 $ 139 As of December 31, Total assets: 2015 2014 2013 Regulated electric $ 3,060 $ 2,984 $ 2,905 Regulated gas 316 322 329 Regulated common assets (1) 111 30 77 Total assets $ 3,487 $ 3,336 $ 3,311 (1) Consists principally of cash and cash equivalents not included in either the regulated electric or regulated natural gas segments.

Transfer of Nonregulated Energy

Transfer of Nonregulated Energy Operations Transfer of Nonregulated Energy Operations	12 Months Ended
	Dec. 31, 2015
MidAmerican Funding, LLC and Subsidiaries [Domain]
Subsequent Event [Line Items]
Subsequent Events [Text Block]	Transfer of Nonregulated Energy Operations Refer to Note 21 of MidAmerican Energy's Notes to Financial Statements.
MidAmerican Energy Company [Member]
Subsequent Event [Line Items]
Subsequent Events [Text Block]	Transfer of Nonregulated Energy Operations In the second quarter of 2015, MidAmerican Energy filed with the IUB and ICC for approval to transfer the assets and liabilities of its unregulated retail services business in a common control transaction to a subsidiary of BHE. MidAmerican Energy's request was approved by the IUB in July 2015 and by the ICC in October 2015. The transfer, which was effective January 1, 2016, was made at MidAmerican Energy’s carrying value of the assets and liabilities as of December 31, 2015, and was recorded by MidAmerican Energy as a dividend. As of and for the year ended December 31, 2015, the financial results of the unregulated retail services business consisted of net assets of $88 million , operating revenue of $905 million , operating income of $22 million , net income of $16 million and cash flows from operating activities of $30 million .

Unaudited Quarterly Operating R

Unaudited Quarterly Operating Results Unaudited Quarterly Operating Results (Notes)	12 Months Ended
	Dec. 31, 2015
MidAmerican Energy Company [Member]
Quarterly Operating Results [Line Items]
Quarterly Financial Information [Text Block]	Unaudited Quarterly Operating Results 2015 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 946 $ 793 $ 920 $ 748 Operating income 106 122 210 33 Net income 94 131 234 3 2014 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 1,225 $ 769 $ 862 $ 884 Operating income 153 51 160 58 Net income 157 32 170 58 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 2015 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 951 $ 797 $ 921 $ 751 Operating income 107 122 211 33 Net income 99 129 231 (1 ) 2014 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 1,230 $ 775 $ 864 $ 893 Operating income 153 51 161 58 Net income 155 30 168 56 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, 2015 2015 2015 2015 Operating revenues $ 459 $ 607 $ 878 $ 458 Operating income 74 136 329 74 Net income 24 60 187 17 Three-Month Periods Ended March 31, June 30, September 30, December 31, 2014 2014 2014 2014 Operating revenues $ 417 $ 595 $ 867 $ 458 Operating income 55 145 307 34 Net income 6 62 168 (9 )
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, 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 Three-Month Periods Ended March 31, June 30, September 30, December 31, 2014 2014 2014 2014 Regulated electric operating revenue $ 177 $ 179 $ 233 $ 190 Regulated natural gas operating revenue 44 21 18 42 Operating income 46 31 60 41 Net income 22 14 31 20

Condensed Financial Statements

Condensed Financial Statements (Notes)	12 Months Ended
	Dec. 31, 2015
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) 2015 2014 ASSETS Current assets: Cash and cash equivalents $ 23 $ 3 Accounts receivable 16 22 Income tax receivable 167 152 Other current assets 2 1 Total current assets 208 178 Investments in subsidiaries 32,505 31,968 Other investments 1,389 1,038 Goodwill 1,221 1,221 Other assets 1,340 1,176 Total assets $ 36,663 $ 35,581 LIABILITIES AND EQUITY Current liabilities: Accounts payable and other current liabilities $ 306 $ 308 Short-term debt 253 395 Total current liabilities 559 703 BHE senior debt 7,814 7,810 BHE junior subordinated debentures 2,944 3,794 Notes payable - affiliate 1,985 1,981 Other long-term liabilities 946 839 Total liabilities 14,248 15,127 Equity: BHE shareholders' equity: Common stock - 115 shares authorized, no par value, 77 shares issued and outstanding — — Additional paid-in capital 6,403 6,423 Retained earnings 16,906 14,513 Accumulated other comprehensive loss, net (908 ) (494 ) Total BHE shareholders' equity 22,401 20,442 Noncontrolling interest 14 12 Total equity 22,415 20,454 Total liabilities and equity $ 36,663 $ 35,581 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) 2015 2014 2013 Operating costs and expenses: General and administration $ 58 $ 51 $ 64 Depreciation and amortization 3 3 1 Total operating costs and expenses 61 54 65 Operating loss (61 ) (54 ) (65 ) Other income (expense): Interest expense (556 ) (476 ) (347 ) Other, net 14 4 25 Total other income (expense) (542 ) (472 ) (322 ) Loss before income tax benefit and equity income (603 ) (526 ) (387 ) Income tax benefit (330 ) (221 ) (345 ) Equity income 2,646 2,402 1,679 Net income 2,373 2,097 1,637 Net income attributable to noncontrolling interest 3 2 1 Net income attributable to BHE shareholders $ 2,370 $ 2,095 $ 1,636 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) 2015 2014 2013 Net income $ 2,373 $ 2,097 $ 1,637 Other comprehensive (loss) income, net of tax (414 ) (397 ) 366 Comprehensive income 1,959 1,700 2,003 Comprehensive income attributable to noncontrolling interests 3 2 1 Comprehensive income attributable to BHE shareholders $ 1,956 $ 1,698 $ 2,002 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) 2015 2014 2013 Cash flows from operating activities $ 2,528 $ 1,937 $ 2,295 Cash flows from investing activities: Investments in subsidiaries (1,506 ) (4,937 ) (6,522 ) Purchases of investments (36 ) (56 ) (106 ) Proceeds from sale of investments 47 35 89 Notes receivable from affiliate, net 19 (55 ) (37 ) Other, net (7 ) (7 ) (16 ) Net cash flows from investing activities (1,483 ) (5,020 ) (6,592 ) Cash flows from financing activities: Proceeds from BHE senior debt — 1,478 1,981 Proceeds from BHE junior subordinated debentures — 1,500 2,594 Proceeds from issuance of BHE common stock — — 1,000 Repayments of BHE senior debt — (250 ) — Repayments of BHE subordinated debt (850 ) (300 ) — Common stock purchases (36 ) — — Net (repayments of) proceeds from short-term debt (142 ) 395 (825 ) Notes payable to affiliate, net 4 (30 ) (173 ) Other, net (1 ) 1 (1 ) Net cash flows from financing activities (1,025 ) 2,794 4,576 Net change in cash and cash equivalents 20 (289 ) 279 Cash and cash equivalents at beginning of year 3 292 13 Cash and cash equivalents at end of year $ 23 $ 3 $ 292 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, 2015 and 2014 , the fair value of BHE 's investment in BYD common stock was $1.2 billion and $881 million , respectively, which resulted in a unrealized gain of $1.0 billion and $649 million as of December 31, 2015 and 2014 , respectively. Dividends and distributions from subsidiaries - Cash dividends paid to BHE by its subsidiaries for the years ended December 31, 2015 , 2014 and 2013 were $3.0 billion , $2.3 billion and $2.5 billion , respectively. In January and February 2016 , BHE received cash dividends from its subsidiaries totaling $187 million . Guarantees and commitments - BHE has issued guarantees up to a maximum of $92 million in support of various obligations of consolidated subsidiaries and commitments to provide equity contributions in support of renewable tax equity investments totaling $478 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, 2015 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 2015 , 2014 and 2013 , 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, 2015
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, 2015 (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 (1) Deductions of Year Reserves Deducted From Assets To Which They Apply: Reserve for uncollectible accounts receivable: Year ended 2015 $ 37 $ 33 $ — $ (39 ) $ 31 Year ended 2014 33 37 — (33 ) 37 Year ended 2013 22 23 9 (21 ) 33 Reserves Not Deducted From Assets (2) : Year ended 2015 $ 11 $ 7 $ — $ (5 ) $ 13 Year ended 2014 9 12 — (10 ) 11 Year ended 2013 9 6 — (6 ) 9 The notes to the consolidated BHE financial statements are an integral part of this financial statement schedule. (1) Acquisition reserves represent the reserves recorded at NV Energy, Inc. at the date of acquisition. (2) 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, 2015 (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 2015 $ 7 $ 7 $ (8 ) $ 6 Year ended 2014 $ 10 $ 7 $ (10 ) $ 7 Year ended 2013 $ 10 $ 7 $ (7 ) $ 10 Reserves Not Deducted From Assets (1) : Year ended 2015 $ 11 $ 7 $ (5 ) $ 13 Year ended 2014 $ 9 $ 12 $ (10 ) $ 11 Year ended 2013 $ 9 $ 6 $ (6 ) $ 9 (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, 2015 (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 2015 $ 7 $ 7 $ (8 ) $ 6 Year ended 2014 $ 10 $ 7 $ (10 ) $ 7 Year ended 2013 $ 10 $ 7 $ (7 ) $ 10 Reserves Not Deducted From Assets (1) : Year ended 2015 $ 11 $ 7 $ (5 ) $ 13 Year ended 2014 $ 9 $ 12 $ (10 ) $ 11 Year ended 2013 $ 9 $ 6 $ (6 ) $ 9 (1) Reserves not deducted from assets include estimated liabilities for losses retained by MidAmerican Energy for workers compensation, public liability and property damage claims.

Summary of Significant Accoun41

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
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, 2015 and 2014 , the allowance for doubtful accounts totaled $31 million and $37 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 $353 million and $320 million as of December 31, 2015 and 2014 , respectively, and materials and supplies totaling $529 million and $506 million as of December 31, 2015 and 2014 , 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 $8 million and $41 million higher as of December 31, 2015 and 2014 , 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 2015 and 2014 , the Company did not record any goodwill impairments. The Company recognized a goodwill impairment of $53 million during 2013. 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, 2015 and 2014 , unbilled revenue was $660 million and $666 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, 2015 and 2014 , these amounts were recognized as regulatory assets of $1.5 billion and $1.4 billion , respectively, and regulatory liabilities of $29 million and $24 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, 2015 . 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 January 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-01, which amends FASB Accounting Standards Codification ("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. In November 2015, the FASB issued ASU No. 2015-17, which amends FASB ASC Topic 740, "Income Taxes." The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. The Company early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in other current assets of $291 million , other current liabilities of $3 million and noncurrent deferred income tax liabilities of $288 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. The Company early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets of $197 million , BHE senior debt of $50 million and subsidiary debt of $147 million as of December 31, 2014. 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. 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. 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 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2015-17, which amends FASB Accounting Standards Codification ("ASC") Topic 740, "Income Taxes". The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. Sierra Pacific early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in current deferred income tax assets and noncurrent deferred income tax liabilities of $42 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. Sierra Pacific early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets and long-term debt of $10 million as of December 31, 2014. 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. 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.
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, 2015 and 2014 , 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): 2015 2014 2013 Beginning balance $ 7 $ 8 $ 9 Charged to operating costs and expenses, net 10 11 13 Write-offs, net (10 ) (12 ) (14 ) Ending balance $ 7 $ 7 $ 8
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 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, 2015 and 2014 , unbilled revenue was $245 million and $243 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 $437 million and $446 million as of December 31, 2015 and 2014 , respectively, and regulatory liabilities of $12 million and $13 million as of December 31, 2015 and 2014 , 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 $23 million and $27 million as of December 31, 2015 and 2014 , 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 January 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-01, which amends FASB Accounting Standards Codification ("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. 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 November 2015, the FASB issued ASU No. 2015-17, which amends ASC Topic 740, "Income Taxes". The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. PacifiCorp early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in current deferred income tax assets of $28 million and noncurrent deferred income tax liabilities of $28 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted, and must be adopted retrospectively for each period presented to reflect the new guidance. PacifiCorp early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets of $34 million and long-term debt of $34 million as of December 31, 2014. 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. 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.
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 investments and nonregulated property, net 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, 2015 and 2014 , the allowance for doubtful accounts totaled $6 million and $7 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 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 Statements of Operations as nonregulated operating revenue for sales contracts and as nonregulated cost of sales for purchase contracts and electricity and natural gas swap contracts. 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. MidAmerican Energy 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 materials and supplies, totaling $105 million and $101 million as of December 31, 2015 and 2014 , respectively, coal stocks, totaling $102 million and $54 million as of December 31, 2015 and 2014 , respectively, and natural gas in storage, totaling $27 million and $24 million as of December 31, 2015 and 2014 , 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 $8 million and $41 million higher as of December 31, 2015 and 2014 , 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. 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, 2015 and 2014 , unbilled revenue was $138 million and $131 million , respectively, and is included in receivables, net on the Balance Sheets. The determination of revenue from an individual customer is based on a systematic reading of meters and 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 compared to normal, total volumes supplied to the system, line losses, economic impacts and composition of customer classes. Estimates are reversed in the following month and actual revenue is recorded based on 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 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, 2015 and 2014 , was $17 million and $25 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, and substantially all of their respective currently payable or receivable income taxes are remitted to or received from BHE. 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, 2015 and 2014 , these amounts were recognized as a net regulatory asset totaling $858 million and $730 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 January 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-01, which amends FASB Accounting Standards Codification ("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 November 2015, the FASB issued ASU No. 2015-17, which amends FASB ASC Topic 740, "Income Taxes." The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. MidAmerican Energy early adopted this guidance as of December 31, 2015, under a retrospective method, resulting in a decrease of $1 million each in other current assets and noncurrent deferred income tax liabilities as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. MidAmerican Energy early adopted this guidance as of December 31, 2015, under a retrospective method, resulting in a decrease of $22 million each in other assets and long-term debt as of December 31, 2014. 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. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016. Early application is not permitted. 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 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 2015 , 2014 and 2013 , 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.
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 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): 2015 2014 2013 Beginning balance $ 14 $ 8 $ 8 Charged to operating costs and expenses, net 16 14 15 Write-offs, net (17 ) (8 ) (15 ) Ending balance $ 13 $ 14 $ 8
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 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.
Inventories [Policy Text Block]	Inventories Inventories consist mainly of materials and supplies totaling $58 million as of December 31 , 2015 and 2014 , and fuel, which includes coal stock, stored natural gas and fuel oil, totaling $22 million and $30 million as of December 31 , 2015 and 2014 , 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 cost of removal 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, 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, 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 2015 and 2014 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. Management's methodology to assess its legal obligation includes an inventory of assets by Nevada Power 's system and components and a review of rights-of-way and easements, regulatory orders, leases and federal, state and local environmental laws. Additionally, management has determined evaporative ponds, dry ash landfills, fuel storage tanks, asbestos and oils treated with Poly Chlorinated Biphenyl have met the requirements for an ARO.
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 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. As substantially all property, plant and equipment was used in regulated businesses as of December 31 , 2015 , 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 , 2015 and 2014 , unbilled revenue was $116 million and $111 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 using the effective interest method.
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 , 2015 and 2014 , these amounts were recognized as regulatory assets of $149 million and $156 million , respectively, and regulatory liabilities of $10 million and $3 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 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2015-17, which amends FASB Accounting Standards Codification ("ASC") Topic 740, "Income Taxes". The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. Nevada Power early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in current deferred income tax assets and noncurrent deferred income tax liabilities of $145 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. Nevada Power early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets and long-term debt of $32 million as of December 31, 2014. 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. 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.
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.
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 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): 2015 2014 2013 Beginning balance $ 2 $ 1 $ 1 Charged to operating costs and expenses, net 1 2 2 Write-offs, net (2 ) (1 ) (2 ) Ending balance $ 1 $ 2 $ 1
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 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.
Inventories [Policy Text Block]	Inventories Inventories consist mainly of materials and supplies totaling $34 million and $32 million as of December 31 , 2015 and 2014 , respectively, and fuel, which includes coal stock, stored natural gas and fuel oil, totaling $5 million and $8 million as of December 31 , 2015 and 2014 , 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 cost of removal 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, 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, 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 2015 and 2014 was 7.62% and 7.58% for electric, 5.97% and 4.96% for natural gas and 7.44% and 7.28% for common facilities, respectively.
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. Management's methodology to assess its legal obligation includes an inventory of assets by Sierra Pacific 's system and components and a review of rights-of-way and easements, regulatory orders, leases and federal, state and local environmental laws. Additionally, management has determined evaporative ponds, dry ash landfills, fuel storage tanks, asbestos and oils treated with Poly Chlorinated Biphenyl have met the requirements for an ARO.
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 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. As substantially all property, plant and equipment was used in regulated businesses as of December 31 , 2015 , 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 , 2015 and 2014 , unbilled revenue was $59 million and $57 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 allocate the natural gas sales between generation and natural gas retail. 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 using the effective interest method.
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 , 2015 and 2014 , these amounts were recognized as regulatory assets of $90 million and $94 million , respectively, and regulatory liabilities of $7 million and $8 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 Accoun42

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In January 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-01, which amends FASB Accounting Standards Codification ("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. In November 2015, the FASB issued ASU No. 2015-17, which amends FASB ASC Topic 740, "Income Taxes." The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. The Company early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in other current assets of $291 million , other current liabilities of $3 million and noncurrent deferred income tax liabilities of $288 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. The Company early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets of $197 million , BHE senior debt of $50 million and subsidiary debt of $147 million as of December 31, 2014. 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. 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. 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 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2015-17, which amends FASB Accounting Standards Codification ("ASC") Topic 740, "Income Taxes". The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. Sierra Pacific early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in current deferred income tax assets and noncurrent deferred income tax liabilities of $42 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. Sierra Pacific early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets and long-term debt of $10 million as of December 31, 2014. 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. 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.
PacifiCorp [Member]
Accounting Policies [Abstract]
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In January 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-01, which amends FASB Accounting Standards Codification ("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. 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 November 2015, the FASB issued ASU No. 2015-17, which amends ASC Topic 740, "Income Taxes". The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. PacifiCorp early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in current deferred income tax assets of $28 million and noncurrent deferred income tax liabilities of $28 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted, and must be adopted retrospectively for each period presented to reflect the new guidance. PacifiCorp early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets of $34 million and long-term debt of $34 million as of December 31, 2014. 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. 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.
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 2015 2014 Property, plant and equipment: Generation 10 - 67 years $ 12,164 $ 11,932 Transmission 58 - 75 years 5,914 5,392 Distribution 20 - 70 years 6,408 6,197 Intangible plant (1) 5 - 62 years 875 879 Other 5 - 60 years 1,396 1,413 Property, plant and equipment in-service 26,757 25,813 Accumulated depreciation and amortization (8,360 ) (8,026 ) Net property, plant and equipment in-service 18,397 17,787 Construction work-in-progress 629 932 Total property, plant and equipment, net $ 19,026 $ 18,719 (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): 2015 2014 2013 Beginning balance $ 7 $ 8 $ 9 Charged to operating costs and expenses, net 10 11 13 Write-offs, net (10 ) (12 ) (14 ) Ending balance $ 7 $ 7 $ 8
MidAmerican Energy Company [Member]
Accounting Policies [Abstract]
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In January 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-01, which amends FASB Accounting Standards Codification ("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 November 2015, the FASB issued ASU No. 2015-17, which amends FASB ASC Topic 740, "Income Taxes." The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. MidAmerican Energy early adopted this guidance as of December 31, 2015, under a retrospective method, resulting in a decrease of $1 million each in other current assets and noncurrent deferred income tax liabilities as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. MidAmerican Energy early adopted this guidance as of December 31, 2015, under a retrospective method, resulting in a decrease of $22 million each in other assets and long-term debt as of December 31, 2014. 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. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016. Early application is not permitted. 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.
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 2015 2014 Utility plant in service: Generation 20-100 years $ 10,404 $ 9,351 Transmission 52-70 years 1,305 1,142 Electric distribution 20-70 years 3,059 2,933 Gas distribution 28-70 years 1,507 1,432 Utility plant in service 16,275 14,858 Accumulated depreciation and amortization (5,229 ) (4,954 ) Utility plant in service, net 11,046 9,904 Nonregulated property, net: Nonregulated property gross 5-45 years 15 14 Accumulated depreciation and amortization (5 ) (5 ) Nonregulated property, net 10 9 11,056 9,913 Construction work in progress 667 606 Property, plant and equipment, net $ 11,723 $ 10,519
Nevada Power Company [Member]
Accounting Policies [Abstract]
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In November 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2015-17, which amends FASB Accounting Standards Codification ("ASC") Topic 740, "Income Taxes". The amendments in this guidance require that deferred income tax liabilities and assets be classified as noncurrent in the balance sheet. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted, and may be adopted prospectively or retrospectively for each period presented to reflect the new guidance. Nevada Power early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in decreases in current deferred income tax assets and noncurrent deferred income tax liabilities of $145 million as of December 31, 2014. In April 2015, the FASB issued ASU No. 2015-03, which amends FASB ASC Subtopic 835-30, "Interest - Imputation of Interest." The amendments in this guidance require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability instead of as an asset. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015, with early adoption permitted. This guidance must be adopted retrospectively, wherein the balance sheet of each period presented should be adjusted to reflect the new guidance. Nevada Power early adopted this guidance as of December 31, 2015 under a retrospective method, resulting in a decrease in other assets and long-term debt of $32 million as of December 31, 2014. 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. 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.
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 2015 2014 Utility plant: Generation 25 - 80 years $ 4,212 $ 4,034 Distribution 20 - 65 years 3,118 3,018 Transmission 45 - 65 years 1,788 1,757 General and intangible plant 5 - 65 years 694 669 Utility plant 9,812 9,478 Accumulated depreciation and amortization (2,971 ) (2,599 ) Utility plant, net 6,841 6,879 Other non-regulated, net of accumulated depreciation and amortization 5 - 65 years 2 4 Plant, net 6,843 6,883 Construction work-in-progress 153 120 Property, plant and equipment, net $ 6,996 $ 7,003
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): 2015 2014 2013 Beginning balance $ 14 $ 8 $ 8 Charged to operating costs and expenses, net 16 14 15 Write-offs, net (17 ) (8 ) (15 ) Ending balance $ 13 $ 14 $ 8
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 2015 2014 Utility plant: Electric generation 40 - 125 years $ 1,134 $ 1,036 Electric distribution 20 - 70 years 1,382 1,321 Electric transmission 50 - 70 years 739 719 Electric general and intangible plant 5 - 65 years 139 123 Natural gas distribution 40 - 70 years 374 366 Natural gas general and intangible plant 8 - 10 years 13 13 Common general 5 - 65 years 265 234 Utility plant 4,046 3,812 Accumulated depreciation and amortization (1,368 ) (1,300 ) Utility plant, net 2,678 2,512 Construction work-in-progress 88 128 Property, plant and equipment, net $ 2,766 $ 2,640
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): 2015 2014 2013 Beginning balance $ 2 $ 1 $ 1 Charged to operating costs and expenses, net 1 2 2 Write-offs, net (2 ) (1 ) (2 ) Ending balance $ 1 $ 2 $ 1

Business Acquisitions (Tables)

Business Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2015
AltaLink [Member]
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Schedule of Business Acquisitions, by Acquisition [Table Text Block]	The following table summarizes the fair values of the assets acquired and liabilities assumed as of the acquisition date (in millions): Fair Value Current assets, including cash and cash equivalents of $15 $ 174 Property, plant and equipment 5,610 Goodwill 1,744 Other long-term assets 141 Total assets 7,669 Current liabilities, including current portion of long-term debt of $79 866 Subsidiary debt, less current portion 3,772 Deferred income taxes 85 Other long-term liabilities 218 Total liabilities 4,941 Net assets acquired $ 2,728
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 2013 Operating revenue $ 17,888 $ 13,130 Net income attributable to BHE shareholders $ 2,155 $ 1,667
NV Energy, Inc. [Member]
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
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, integration and other costs incurred by both BHE and NV Energy during 2013 totaling $74 million , after-tax, a one-time bill credit to retail customers of $13 million , after-tax, and the amortization of the purchase price adjustments each assuming the acquisition had taken place on January 1, 2012 (in millions): 2013 Operating revenue $ 15,561 Net income attributable to BHE shareholders $ 1,867

Property, Plant and Equipment44

Property, Plant and Equipment, Net (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 Regulated assets: Utility generation, transmission and distribution systems 5-80 years $ 69,248 $ 64,645 Interstate natural gas pipeline assets 3-80 years 6,755 6,660 76,003 71,305 Accumulated depreciation and amortization (22,682 ) (21,447 ) Regulated assets, net 53,321 49,858 Nonregulated assets: Independent power plants 5-30 years 4,751 4,362 Other assets 3-30 years 875 673 5,626 5,035 Accumulated depreciation and amortization (805 ) (839 ) Nonregulated assets, net 4,821 4,196 Net operating assets 58,142 54,054 Construction work-in-progress 2,627 5,194 Property, plant and equipment, net $ 60,769 $ 59,248
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 2015 2014 Utility plant in service: Generation 20-100 years $ 10,404 $ 9,351 Transmission 52-70 years 1,305 1,142 Electric distribution 20-70 years 3,059 2,933 Gas distribution 28-70 years 1,507 1,432 Utility plant in service 16,275 14,858 Accumulated depreciation and amortization (5,229 ) (4,954 ) Utility plant in service, net 11,046 9,904 Nonregulated property, net: Nonregulated property gross 5-45 years 15 14 Accumulated depreciation and amortization (5 ) (5 ) Nonregulated property, net 10 9 11,056 9,913 Construction work in progress 667 606 Property, plant and equipment, net $ 11,723 $ 10,519
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: 2015 2014 2013 Electric 3.0 % 2.8 % 3.3 % Gas 2.9 % 2.8 % 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 2015 2014 Property, plant and equipment: Generation 10 - 67 years $ 12,164 $ 11,932 Transmission 58 - 75 years 5,914 5,392 Distribution 20 - 70 years 6,408 6,197 Intangible plant (1) 5 - 62 years 875 879 Other 5 - 60 years 1,396 1,413 Property, plant and equipment in-service 26,757 25,813 Accumulated depreciation and amortization (8,360 ) (8,026 ) Net property, plant and equipment in-service 18,397 17,787 Construction work-in-progress 629 932 Total property, plant and equipment, net $ 19,026 $ 18,719 (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 2015 2014 Utility plant: Generation 25 - 80 years $ 4,212 $ 4,034 Distribution 20 - 65 years 3,118 3,018 Transmission 45 - 65 years 1,788 1,757 General and intangible plant 5 - 65 years 694 669 Utility plant 9,812 9,478 Accumulated depreciation and amortization (2,971 ) (2,599 ) Utility plant, net 6,841 6,879 Other non-regulated, net of accumulated depreciation and amortization 5 - 65 years 2 4 Plant, net 6,843 6,883 Construction work-in-progress 153 120 Property, plant and equipment, net $ 6,996 $ 7,003
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 2015 2014 Utility plant: Electric generation 40 - 125 years $ 1,134 $ 1,036 Electric distribution 20 - 70 years 1,382 1,321 Electric transmission 50 - 70 years 739 719 Electric general and intangible plant 5 - 65 years 139 123 Natural gas distribution 40 - 70 years 374 366 Natural gas general and intangible plant 8 - 10 years 13 13 Common general 5 - 65 years 265 234 Utility plant 4,046 3,812 Accumulated depreciation and amortization (1,368 ) (1,300 ) Utility plant, net 2,678 2,512 Construction work-in-progress 88 128 Property, plant and equipment, net $ 2,766 $ 2,640

Jointly Owned Utility Facilit45

Jointly Owned Utility Facilities (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 (dollars in millions): Accumulated Construction Company Facility In Depreciation and Work-in- Share Service Amortization Progress PacifiCorp: Jim Bridger Nos. 1-4 67 % $ 1,289 $ 566 $ 83 Hunter No. 1 94 469 154 — Hunter No. 2 60 293 94 — Wyodak 80 457 198 3 Colstrip Nos. 3 and 4 10 239 128 2 Hermiston (1) 50 177 71 1 Craig Nos. 1 and 2 19 325 213 18 Hayden No. 1 25 76 30 — Hayden No. 2 13 30 18 7 Foote Creek 79 39 24 — Transmission and distribution facilities Various 577 178 46 Total PacifiCorp 3,971 1,674 160 MidAmerican Energy: Louisa No. 1 88 % 757 405 7 Quad Cities Nos. 1 and 2 (2) 25 672 340 27 Walter Scott, Jr. No. 3 79 608 297 6 Walter Scott, Jr. No. 4 (3) 60 448 91 — George Neal No. 4 41 305 148 1 Ottumwa No. 1 52 554 184 3 George Neal No. 3 72 415 153 — Transmission facilities Various 245 83 2 Total MidAmerican Energy 4,004 1,701 46 NV Energy: Navajo 11 % 203 141 1 Silverhawk 75 247 58 2 Valmy 50 382 209 2 Transmission facilities Various 224 39 1 Total NV Energy 1,056 447 6 BHE Pipeline Group - common facilities Various 285 158 1 Total $ 9,316 $ 3,980 $ 213 (1) PacifiCorp has contracted to purchase the remaining 50% of the output of the Hermiston generating facility. (2) Includes amounts related to nuclear fuel. (3) Facility in-service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling $319 million and $67 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, 2015 (dollars in millions): Facility Accumulated Construction PacifiCorp in Depreciation and Work-in- Share Service Amortization Progress Jim Bridger Nos. 1 - 4 67 % $ 1,289 $ 566 $ 83 Hunter No. 1 94 469 154 — Hunter No. 2 60 293 94 — Wyodak 80 457 198 3 Colstrip Nos. 3 and 4 10 239 128 2 Hermiston (1) 50 177 71 1 Craig Nos. 1 and 2 19 325 213 18 Hayden No. 1 25 76 30 — Hayden No. 2 13 30 18 7 Foote Creek 79 39 24 — Transmission and distribution facilities Various 577 178 46 Total $ 3,971 $ 1,674 $ 160 (1) As discussed in Note 17, PacifiCorp has contracted to purchase the remaining 50% of the output of the Hermiston generating facility.
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, 2015 (dollars in millions): Accumulated Construction Company Plant in Depreciation and Work in Share Service Amortization Progress Louisa Unit No. 1 88.0 % $ 757 $ 405 $ 7 Quad Cities Unit Nos. 1 & 2 (1) 25.0 672 340 27 Walter Scott, Jr. Unit No. 3 79.1 608 297 6 Walter Scott, Jr. Unit No. 4 (2) 59.7 448 91 — George Neal Unit No. 4 40.6 305 148 1 Ottumwa Unit No. 1 52.0 554 184 3 George Neal Unit No. 3 72.0 415 153 — Transmission facilities (3) Various 245 83 2 Total $ 4,004 $ 1,701 $ 46 (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 $67 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 , 2015 (dollars in millions): Nevada Construction Power's Facility In Accumulated Work-in- Share Service Depreciation Progress Silverhawk Generating Station 75% $ 247 $ 58 $ 2 Navajo Generating Station 11 203 141 1 ON Line Transmission Line 24 144 8 1 Other Transmission Facilities Various 68 28 — Total $ 662 $ 235 $ 4
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 , 2015 (dollars in millions): Sierra Construction Pacific's Facility In Accumulated Work-in- Share Service Depreciation Progress Valmy Generating Station 50% $ 382 $ 209 $ 2 ON Line Transmission Line 1 8 1 — Valmy Transmission 50 4 2 — Total $ 394 $ 212 $ 2

Regulatory Matters (Tables)

Regulatory Matters (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 Deferred income taxes (1) 26 years $ 1,577 $ 1,468 Employee benefit plans (2) 9 years 778 747 Asset disposition costs (3) Various 307 329 Deferred net power costs 1 year 140 277 Asset retirement obligations 8 years 281 239 Unrealized loss on regulated derivative contracts 5 years 250 223 Abandoned projects 5 years 136 159 Unamortized contract values 8 years 110 123 Other Various 706 688 Total regulatory assets $ 4,285 $ 4,253 Reflected as: Current assets $ 130 $ 253 Noncurrent assets 4,155 4,000 Total regulatory assets $ 4,285 $ 4,253 (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) Includes amounts 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. 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 2015 2014 Cost of removal (1) 28 years $ 2,167 $ 2,215 Deferred net power costs 2 years 206 — Asset retirement obligations 22 years 147 169 Levelized depreciation 26 years 199 169 Employee benefit plans (2) 12 years 13 20 Other Various 301 259 Total regulatory liabilities $ 3,033 $ 2,832 Reflected as: Current liabilities $ 402 $ 163 Noncurrent liabilities 2,631 2,669 Total regulatory liabilities $ 3,033 $ 2,832 (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 2015 2014 Deferred income taxes (1) 26 years $ 437 $ 446 Employee benefit plans (2) 8 years 499 491 Utah mine disposition (3) Various 186 194 Unamortized contract values 8 years 110 123 Deferred net power costs 1 year 86 122 Unrealized loss on derivative contracts 5 years 133 85 Other Various 234 244 Total regulatory assets $ 1,685 $ 1,705 Reflected as: Current assets $ 102 $ 131 Noncurrent assets 1,583 1,574 Total regulatory assets $ 1,685 $ 1,705 (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 2015 2014 Cost of removal (1) 26 years $ 894 $ 873 Deferred income taxes Various 12 13 Other Various 66 58 Total regulatory liabilities $ 972 $ 944 Reflected as: Current liabilities $ 34 $ 34 Noncurrent liabilities 938 910 Total regulatory liabilities $ 972 $ 944 (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 2015 2014 Deferred income taxes, net (1) 25 years $ 858 $ 730 Asset retirement obligations (2) 6 years 94 62 Employee benefit plans (3) 11 years 39 42 Unrealized loss on regulated derivative contracts 1 year 20 38 Other Various 33 36 Total $ 1,044 $ 908 (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 11 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 2015 2014 Cost of removal accrual (1) 25 years $ 653 $ 642 Asset retirement obligations (2) 22 years 140 159 Other Various 38 36 Total $ 831 $ 837 (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 11 for a discussion of asset retirement obligations.
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 2015 2014 Deferred income taxes (1) 28 years $ 149 $ 156 Merger costs from 1999 merger 28 years 143 149 Decommissioning costs 7 years 121 113 Employee benefit plans (2) 10 years 98 85 Abandoned projects 4 years 91 107 Deferred operating costs 20 years 87 61 Asset retirement obligations 7 years 79 80 Legacy meters 17 years 64 68 Deferred energy costs 2 years 56 129 Other Various 169 178 Total regulatory assets $ 1,057 $ 1,126 Reflected as: Current assets $ — $ 57 Other assets 1,057 1,069 Total regulatory assets $ 1,057 $ 1,126 (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 2015 2014 Cost of removal (1) 34 years $ 273 $ 295 Deferred energy costs 2 years 139 — Energy efficiency program 1 year 34 25 Other Various 31 46 Total regulatory liabilities $ 477 $ 366 Reflected as: Current liabilities $ 173 $ 40 Other long-term liabilities 304 326 Total regulatory liabilities $ 477 $ 366 (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 2015 2014 Employee benefit plans (2) 10 years $ 126 $ 115 Deferred income taxes (1) 28 years 90 94 Merger costs from 1999 merger 31 years 83 87 Abandoned projects 9 years 44 51 Deferred energy costs 2 years — 32 Loss on reacquired debt 17 years 22 24 Other Various 67 73 Total regulatory assets $ 432 $ 476 Reflected as: Current assets $ — $ 32 Other assets 432 444 Total regulatory assets $ 432 $ 476 (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. 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 2015 2014 Cost of removal (1) 40 years $ 208 $ 233 Deferred energy costs 2 years 66 — Renewable energy program 1 year 8 32 Other Various 26 36 Total regulatory liabilities $ 308 $ 301 Reflected as: Current liabilities $ 78 $ 39 Other long-term liabilities 230 262 Total regulatory liabilities $ 308 $ 301 (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 Ca47

Investments and Restricted Cash and Investments (Tables)	12 Months Ended
	Dec. 31, 2015
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): 2015 2014 Investments: BYD Company Limited common stock $ 1,238 $ 881 Rabbi trusts 380 386 Other 130 126 Total investments 1,748 1,393 Equity method investments: Electric Transmission Texas, LLC 585 515 Bridger Coal Company 190 192 BHE Renewables tax equity investments 168 — Other 160 161 Total equity method investments 1,103 868 Restricted cash and investments: Quad Cities Station nuclear decommissioning trust funds 429 424 Solar Star and Topaz Projects 95 66 Other 129 167 Total restricted cash and investments 653 657 Total investments and restricted cash and investments $ 3,504 $ 2,918 Reflected as: Current assets $ 137 $ 115 Noncurrent assets 3,367 2,803 Total investments and restricted cash and investments $ 3,504 $ 2,918
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): 2015 2014 Nuclear decommissioning trust $ 429 $ 424 Rabbi trusts 175 175 Auction rate securities 26 26 Other 4 — Total $ 634 $ 625

Short-Term Debt and Credit Fa48

Short-Term Debt and Credit Facilities (Tables)	12 Months Ended
	Dec. 31, 2015
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) 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 2014: Credit facilities $ 2,000 $ 1,200 $ 609 $ 650 $ 265 $ 1,119 $ 853 $ 6,696 Less: Short-term debt (395 ) (20 ) (50 ) — (215 ) (251 ) (514 ) (1,445 ) Tax-exempt bond support and letters of credit (28 ) (398 ) (195 ) — — (4 ) — (625 ) Net credit facilities $ 1,577 $ 782 $ 364 $ 650 $ 50 $ 864 $ 339 $ 4,626 (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, 2015 , the Company was in compliance with the covenants of its credit facilities and letter of credit arrangements. BHE BHE has a $1.4 billion senior unsecured credit facility expiring in June 2017 and a $600 million senior unsecured credit facility expiring in June 2017. These credit facilities have a variable interest rate based on the London Interbank Offered Rate ("LIBOR") or a base rate, at BHE 's option, plus a spread that varies based on BHE 's credit ratings for its senior unsecured long-term debt securities. These credit facilities are for general corporate purposes and also support BHE 's commercial paper program and provide for the issuance of letters of credit. As of December 31, 2015 and 2014 , the weighted average interest rate on commercial paper borrowings outstanding was 0.66% and 0.49% , respectively. These credit facilities require 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, 2015 and 2014 , BHE had $142 million and $125 million , respectively, of letters of credit outstanding, of which $51 million and $28 million as of December 31, 2015 and 2014 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 2016. PacifiCorp PacifiCorp has a $600 million unsecured credit facility expiring in June 2017 and a $600 million unsecured credit facility expiring in March 2018. 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, 2015 and 2014 , the weighted average interest rate on commercial paper borrowings outstanding was 0.65% and 0.43% , 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, 2015 and 2014 , PacifiCorp had $310 million and $451 million , respectively, of fully available letters of credit issued under committed arrangements, of which $10 million and $270 million as of December 31, 2015 and 2014 were issued under the credit facilities. These letters of credit support PacifiCorp's variable-rate tax-exempt bond obligations and expire through March 2017. MidAmerican Funding 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 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, 2014 , the weighted average interest rate on commercial paper borrowings outstanding was 0.35% . 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. 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. As of December 31, 2014 , $184 million was outstanding under the credit facility, with a weighted average interest rate of 1.75% . 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. Additionally, as of December 31, 2014 , Northern Powergrid had $31 million drawn on uncommitted bank facilities totaling £42 million , with a weighted average interest rate of 2.0% . AltaLink ALP has a C$750 million secured revolving credit facility expiring in December 2017, which provides support for borrowings under the unsecured commercial paper program and may also be used for general corporate purposes. The credit facility 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 2017, which may be used for general corporate purposes, capital expenditures and letters of credit. The credit facility 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, 2015 and 2014 , ALP had $324 million and $104 million outstanding under these facilities at a weighted average interest rate of 0.85% and 1.26% , respectively. AltaLink Investments, L.P. has a C$300 million unsecured revolving term credit facility expiring in December 2020, which may be used for operating expenses, capital expenditures, working capital needs and letters of credit to a maximum of C$10 million . The credit facility 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 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 facility requires 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, 2015 and 2014 , AltaLink Investments, L.P. had $77 million and $147 million outstanding under this facility at a weighted average interest rate of 0.89% and 1.30% , 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, 2014 , HomeServices had $243 million outstanding under its credit facility with a weighted average interest rate of 1.41% . Through its subsidiaries, HomeServices maintains mortgage lines of credit totaling $578 million and $503 million as of December 31, 2015 and 2014 , respectively, used for mortgage banking activities that expire beginning in February 2016 through December 2016 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, 2015 and 2014 , HomeServices had $300 million and $271 million , respectively, outstanding under these mortgage lines of credit at a weighted average interest rate of 2.42% and 2.25% , 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 $646 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, (c) provide security for remediation and mitigation liabilities, and (d) provide security in respect of conditional use permit sales tax obligations. As of December 31, 2015 and 2014 , $600 million and $245 million , respectively, of letters of credit had been issued under these facilities. As of December 31, 2015 and 2014 , certain renewable projects collectively have letters of credit outstanding of $65 million and $63 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) 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 2014: Credit facilities $ 2,000 $ 1,200 $ 609 $ 650 $ 265 $ 1,119 $ 853 $ 6,696 Less: Short-term debt (395 ) (20 ) (50 ) — (215 ) (251 ) (514 ) (1,445 ) Tax-exempt bond support and letters of credit (28 ) (398 ) (195 ) — — (4 ) — (625 ) Net credit facilities $ 1,577 $ 782 $ 364 $ 650 $ 50 $ 864 $ 339 $ 4,626 (1) The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.
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): 2015: Credit facilities $ 1,200 Less: Short-term debt (20 ) Tax-exempt bond support and letters of credit (160 ) Net credit facilities $ 1,020 2014: Credit facilities $ 1,200 Less: Short-term debt (20 ) Letters of credit and tax-exempt bond support (398 ) Net credit facilities $ 782 PacifiCorp has a $600 million unsecured credit facility expiring in June 2017 and a $600 million unsecured credit facility expiring in March 2018. 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, 2015 and 2014 , the weighted average interest rate on commercial paper borrowings outstanding was 0.65% and 0.43% , 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, 2015 , PacifiCorp was in compliance with the covenants of its credit facilities. As of December 31, 2015 and 2014 , PacifiCorp had $310 million and $451 million , respectively, of fully available letters of credit issued under committed arrangements, of which $10 million and $270 million as of December 31, 2015 and 2014 were issued under the credit facilities. These letters of credit support PacifiCorp's variable-rate tax-exempt bond obligations and expire through March 2017. As of December 31, 2015 , PacifiCorp had approximately $15 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, 2015 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): 2015: Credit facilities $ 1,200 Less: Short-term debt (20 ) Tax-exempt bond support and letters of credit (160 ) Net credit facilities $ 1,020 2014: Credit facilities $ 1,200 Less: Short-term debt (20 ) Letters of credit and tax-exempt bond support (398 ) Net credit facilities $ 782
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 2016 and has a variable interest rate based on LIBOR plus a spread. As of December 31, 2014 , the weighted average interest rate on commercial paper borrowings outstanding was 0.35% . 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, 2015 , 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 June 30, 2016 . The following table summarizes MidAmerican Energy's availability under its two unsecured revolving credit facilities as of December 31 (in millions): 2015 2014 Credit facilities $ 605 $ 605 Less: Short-term debt outstanding — (50 ) Variable-rate tax-exempt bond support (195 ) (195 ) Net credit facilities $ 410 $ 360
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): 2015 2014 Credit facilities $ 605 $ 605 Less: Short-term debt outstanding — (50 ) Variable-rate tax-exempt bond support (195 ) (195 ) Net credit facilities $ 410 $ 360
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 , 2015 and 2014 , 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, 2015
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 2015 2014 Junior subordinated debentures, due 2043 $ 1,444 $ 1,444 $ 2,294 Junior subordinated debentures, due 2044 1,500 1,500 1,500 Total BHE junior subordinated debentures - noncurrent $ 2,944 $ 2,944 $ 3,794 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 2015 2014 1.10% Senior Notes, due 2017 $ 400 $ 399 $ 399 5.75% Senior Notes, due 2018 650 648 648 2.00% Senior Notes, due 2018 350 348 348 2.40% Senior Notes, due 2020 350 348 348 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 1,688 5.95% Senior Bonds, due 2037 550 547 547 6.50% Senior Bonds, due 2037 1,000 987 986 5.15% Senior Notes, due 2043 750 739 738 4.50% Senior Notes, due 2045 750 737 737 Total BHE Senior Debt $ 7,875 $ 7,814 $ 7,810 Reflected as: Current liabilities $ — $ — Noncurrent liabilities 7,814 7,810 Total BHE Senior Debt $ 7,814 $ 7,810 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 2015 2014 PacifiCorp $ 7,204 $ 7,159 $ 7,055 MidAmerican Funding 4,627 4,560 4,323 NV Energy 4,840 4,860 5,118 Northern Powergrid 2,735 2,772 2,317 BHE Pipeline Group 1,045 1,040 1,358 BHE Transmission 3,469 3,467 3,743 BHE Renewables 3,394 3,356 2,934 Total subsidiary debt $ 27,314 $ 27,214 $ 26,848 Reflected as: Current liabilities $ 1,148 $ 1,232 Noncurrent liabilities 26,066 25,616 Total subsidiary debt $ 27,214 $ 26,848 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 2015 2014 First mortgage bonds: 2.40%, due 2019 $ 500 $ 499 $ 498 3.70%, due 2023 250 248 248 3.50%, due 2024 500 502 296 4.80%, due 2043 350 345 345 4.40%, due 2044 400 394 394 4.25%, due 2046 450 444 — Notes: 5.95% Series, due 2017 250 250 250 5.3% Series, due 2018 350 349 349 6.75% Series, due 2031 400 395 395 5.75% Series, due 2035 300 298 298 5.8% Series, due 2036 350 347 347 Turbine purchase obligation, 1.43%, due 2015 (1) — — 420 Transmission upgrade obligation, 4.449%, due through 2035 5 4 — Variable-rate tax-exempt bond obligation series: (weighted average interest rate- 2015-0.03%, 2014-0.07%) Due 2016 34 33 33 Due 2017 4 4 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 2038 45 45 45 Capital lease obligations - 4.16%, due through 2020 2 2 — Total $ 4,302 $ 4,271 $ 4,034 (1) In conjunction with the construction of wind-powered generating facilities in 2012, MidAmerican Energy accrued as gross property, plant and equipment amounts for turbine purchases it is not contractually obligated to pay until December 2015. The amount ultimately payable was discounted and recognized upon delivery of the equipment as long-term debt. The discount was amortized as interest expense over the period until payment was due using the effective interest method.

Subsidiary Debt (Tables)

Subsidiary Debt (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 Junior subordinated debentures, due 2043 $ 1,444 $ 1,444 $ 2,294 Junior subordinated debentures, due 2044 1,500 1,500 1,500 Total BHE junior subordinated debentures - noncurrent $ 2,944 $ 2,944 $ 3,794 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 2015 2014 1.10% Senior Notes, due 2017 $ 400 $ 399 $ 399 5.75% Senior Notes, due 2018 650 648 648 2.00% Senior Notes, due 2018 350 348 348 2.40% Senior Notes, due 2020 350 348 348 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 1,688 5.95% Senior Bonds, due 2037 550 547 547 6.50% Senior Bonds, due 2037 1,000 987 986 5.15% Senior Notes, due 2043 750 739 738 4.50% Senior Notes, due 2045 750 737 737 Total BHE Senior Debt $ 7,875 $ 7,814 $ 7,810 Reflected as: Current liabilities $ — $ — Noncurrent liabilities 7,814 7,810 Total BHE Senior Debt $ 7,814 $ 7,810 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 2015 2014 PacifiCorp $ 7,204 $ 7,159 $ 7,055 MidAmerican Funding 4,627 4,560 4,323 NV Energy 4,840 4,860 5,118 Northern Powergrid 2,735 2,772 2,317 BHE Pipeline Group 1,045 1,040 1,358 BHE Transmission 3,469 3,467 3,743 BHE Renewables 3,394 3,356 2,934 Total subsidiary debt $ 27,314 $ 27,214 $ 26,848 Reflected as: Current liabilities $ 1,148 $ 1,232 Noncurrent liabilities 26,066 25,616 Total subsidiary debt $ 27,214 $ 26,848 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 2015 2014 First mortgage bonds: 2.40%, due 2019 $ 500 $ 499 $ 498 3.70%, due 2023 250 248 248 3.50%, due 2024 500 502 296 4.80%, due 2043 350 345 345 4.40%, due 2044 400 394 394 4.25%, due 2046 450 444 — Notes: 5.95% Series, due 2017 250 250 250 5.3% Series, due 2018 350 349 349 6.75% Series, due 2031 400 395 395 5.75% Series, due 2035 300 298 298 5.8% Series, due 2036 350 347 347 Turbine purchase obligation, 1.43%, due 2015 (1) — — 420 Transmission upgrade obligation, 4.449%, due through 2035 5 4 — Variable-rate tax-exempt bond obligation series: (weighted average interest rate- 2015-0.03%, 2014-0.07%) Due 2016 34 33 33 Due 2017 4 4 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 2038 45 45 45 Capital lease obligations - 4.16%, due through 2020 2 2 — Total $ 4,302 $ 4,271 $ 4,034 (1) In conjunction with the construction of wind-powered generating facilities in 2012, MidAmerican Energy accrued as gross property, plant and equipment amounts for turbine purchases it is not contractually obligated to pay until December 2015. The amount ultimately payable was discounted and recognized upon delivery of the equipment as long-term debt. The discount was amortized as interest expense over the period until payment was due using the effective interest method.
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, 2016 and thereafter, excluding fair value adjustments and unamortized premiums, discounts and debt issuance costs, are as follows (in millions): 2021 and 2016 2017 2018 2019 2020 Thereafter Total BHE senior notes $ — $ 400 $ 1,000 $ — $ 350 $ 6,125 $ 7,875 BHE junior subordinated debentures — — — — — 2,944 2,944 PacifiCorp 81 57 589 353 41 6,083 7,204 MidAmerican Funding 34 254 350 500 1 3,488 4,627 NV Energy 676 16 840 519 336 2,453 4,840 Northern Powergrid — — 59 59 500 2,117 2,735 BHE Pipeline Group 54 62 329 — — 600 1,045 BHE Transmission 110 — 145 145 235 2,834 3,469 BHE Renewables 193 196 208 494 126 2,177 3,394 Totals $ 1,148 $ 985 $ 3,520 $ 2,070 $ 1,589 $ 28,821 $ 38,133
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, 2016 , and thereafter, excluding unamortized premiums, discounts and debt issuance costs, are as follows (in millions): 2016 $ 34 2017 254 2018 351 2019 500 2020 1 2021 and thereafter 3,162
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 2015 2014 General and Refunding Mortgage Securities: 6.000% Series M, due 2016 $ 450 $ 450 $ 451 3.375% Series T, due 2023 250 248 247 6.750% Series P, due 2037 252 255 255 Variable-rate series (2015-0.733% to 1.054%, 2014-0.464% to 0.466%): Pollution Control Revenue Bonds Series 2006A, due 2031 58 58 58 Pollution Control Revenue Bonds Series 2006B, due 2036 75 74 74 Pollution Control Revenue Bonds Series 2006C, due 2036 81 80 79 Capital and financial lease obligations - 2.700% to 8.548%, due through 2054 37 37 26 Total long-term debt and financial and capital leases $ 1,203 $ 1,202 $ 1,190 Reflected as: Current portion of long-term debt and financial and capital lease obligations $ 453 $ 1 Long-term debt and financial and capital lease obligations 749 1,189 Total long-term debt and financial and capital leases $ 1,202 $ 1,190
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, 2016 and thereafter, are as follows (in millions): Long-term Capital and Financial Debt Lease Obligations Total 2016 $ 450 $ 6 $ 456 2017 — 4 4 2018 — 4 4 2019 — 4 4 2020 — 3 3 Thereafter 716 53 769 Total 1,166 74 1,240 Unamortized premium, discount and debt issuance cost (1 ) — (1 ) Amounts representing interest — (37 ) (37 ) Total $ 1,165 $ 37 $ 1,202
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 2015 2014 General and Refunding Mortgage Securities: 5.875% Series L, due 2015 $ — $ — $ 250 5.950% Series M, due 2016 210 210 209 6.500% Series O, due 2018 324 323 322 6.500% Series S, due 2018 499 498 497 7.125% Series V, due 2019 500 499 499 6.650% Series N, due 2036 367 356 356 6.750% Series R, due 2037 349 345 345 5.375% Series X, due 2040 250 247 247 5.450% Series Y, due 2041 250 235 234 Variable-rate series (2015-0.672% to 1.055%, 2014-0.455% to 0.464%): 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 497 497 510 Total long-term debt and financial and capital leases $ 3,322 $ 3,285 $ 3,544 Reflected as: Current portion of long-term debt and financial and capital lease obligations $ 225 $ 264 Long-term debt and financial and capital lease obligations 3,060 3,280 Total long-term debt and financial and capital leases $ 3,285 $ 3,544
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, 2016 and thereafter, are as follows (in millions): Long-term Capital and Financial Debt Lease Obligations Total 2016 $ 210 $ 73 $ 283 2017 — 75 75 2018 823 74 897 2019 500 75 575 2020 — 74 74 Thereafter 1,292 908 2,200 Total 2,825 1,279 4,104 Unamortized premium, discount and debt issuance cost (37 ) — (37 ) Executory costs — (129 ) (129 ) Amounts representing interest — (653 ) (653 ) Total $ 2,788 $ 497 $ 3,285
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 2015 2014 First mortgage bonds: 5.50% to 8.635%, due through 2019 $ 855 $ 853 $ 859 2.95% to 8.53%, due 2021 to 2025 2,149 2,137 1,888 6.71% due 2026 100 100 100 5.25% to 7.70%, due 2031 to 2035 800 794 793 5.75% to 6.35%, due 2036 to 2039 2,500 2,480 2,479 4.10% due 2042 300 297 297 Variable-rate series, tax-exempt bond obligations (2015-0.01% to 0.22%; 2014-0.02% to 0.22%): Due 2018 to 2025 (1) 107 107 223 Due 2016 to 2024 (1)(2) 198 196 219 Due 2016 to 2025 (2) 59 59 36 Due 2017 to 2018 91 91 91 Capital lease obligations - 8.75% to 15.678%, due through 2035 45 45 70 Total PacifiCorp $ 7,204 $ 7,159 $ 7,055 (1) Supported by $310 million and $451 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2015 and 2014 , 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 and capital lease obligations were as follows as of December 31 (dollars in millions): 2015 2014 Average Average Principal Carrying Interest Carrying Interest Amount Value Rate Value Rate First mortgage bonds: 5.50% to 8.635%, due through 2019 $ 855 $ 853 5.61 % $ 859 5.63 % 2.95% to 8.53%, due 2021 to 2025 2,149 2,137 4.01 1,888 4.09 6.71% due 2026 100 100 6.71 100 6.71 5.25% to 7.70%, due 2031 to 2035 800 794 6.33 793 6.33 5.75% to 6.35%, due 2036 to 2039 2,500 2,480 6.06 2,479 6.06 4.10% due 2042 300 297 4.10 297 4.10 Tax-exempt bond obligations: Variable rates, due 2018 to 2025 (1) 107 107 0.01 223 0.03 Variable rates, due 2016 to 2024 (1)(2) 198 196 0.02 219 0.02 Variable rates, due 2016 to 2025 (2) 59 59 0.21 36 0.22 Variable rates, due 2017 to 2018 91 91 0.22 91 0.22 Total long-term debt 7,159 7,114 6,985 Capital lease obligations: 8.75% to 14.61%, due through 2035 32 32 11.25 34 11.33 Total long-term debt and capital lease obligations $ 7,191 $ 7,146 $ 7,019 Reflected as: 2015 2014 Current portion of long-term debt and capital lease obligations $ 68 $ 134 Long-term debt and capital lease obligations 7,078 6,885 Total long-term debt and capital lease obligations $ 7,146 $ 7,019 1) Supported by $310 million and $451 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2015 and 2014 , 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, 2015 , the annual principal maturities of long-term debt and total capital lease obligations for 2016 and thereafter are as follows (in millions): Long-term Capital Lease Debt Obligations Total 2016 $ 66 $ 5 $ 71 2017 52 10 62 2018 586 5 591 2019 350 5 355 2020 38 4 42 Thereafter 6,067 27 6,094 Total 7,159 56 7,215 Unamortized discount and debt issuance costs (45 ) — (45 ) Amounts representing interest — (24 ) (24 ) Total $ 7,114 $ 32 $ 7,146
MidAmerican Funding LLC [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 2015 2014 MidAmerican Funding: 6.927% Senior Bonds, due 2029 $ 325 $ 289 $ 289 MidAmerican Energy: Tax-exempt bond obligations - Variable-rate series (2015-0.03%, 2014-0.07%), due 2016-2038 195 194 194 First Mortgage Bonds: 2.40%, due 2019 500 499 498 3.70%, due 2023 250 248 248 3.50%, due 2024 500 502 296 4.80%, due 2043 350 345 345 4.40%, due 2044 400 394 394 4.25%, due 2046 450 444 — Notes: 5.95% Series, due 2017 250 250 250 5.3% Series, due 2018 350 349 349 6.75% Series, due 2031 400 395 395 5.75% Series, due 2035 300 298 298 5.8% Series, due 2036 350 347 347 Turbine purchase obligation, 1.43% due 2015 (1) — — 420 Transmission upgrade obligation, 4.45% due through 2035 5 4 — Capital lease obligations - 4.16%, due through 2020 2 2 — Total MidAmerican Energy 4,302 4,271 4,034 Total MidAmerican Funding $ 4,627 $ 4,560 $ 4,323 (1) In conjunction with the construction of wind-powered generating facilities in 2012, MidAmerican Energy accrued as property, plant and equipment amounts for turbine purchases it was not contractually obligated to pay until December 2015. The amount ultimately payable was discounted and recognized upon delivery of the equipment as long-term debt. The discount was amortized as interest expense over the period until payment was due using the effective interest method.
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 2015 2014 NV Energy - 6.250% Senior Notes, due 2020 $ 315 $ 373 $ 384 Nevada Power: General and Refunding Mortgage Securities: 5.875% Series L, due 2015 — — 250 5.950% Series M, due 2016 210 210 209 6.500% Series O, due 2018 324 323 322 6.500% Series S, due 2018 499 498 497 7.125% Series V, due 2019 500 499 499 6.650% Series N, due 2036 367 356 356 6.750% Series R, due 2037 349 345 345 5.375% Series X, due 2040 250 247 247 5.450% Series Y, due 2041 250 235 234 Variable-rate series (2015-0.672% to 1.055%, 2014-0.455% to 0.464%): 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 497 497 510 Total Nevada Power 3,322 3,285 3,544 Sierra Pacific: General and Refunding Mortgage Securities: 6.000% Series M, due 2016 450 450 451 3.375% Series T, due 2023 250 248 247 6.750% Series P, due 2037 252 255 255 Variable-rate series (2015-0.733% to 1.054%, 2014-0.464% to 0.466%): Pollution Control Revenue Bonds Series 2006A, due 2031 58 58 58 Pollution Control Revenue Bonds Series 2006B, due 2036 75 74 74 Pollution Control Revenue Bonds Series 2006C, due 2036 81 80 79 Capital and financial lease obligations - 2.700% to 8.548%, due through 2054 37 37 26 Total Sierra Pacific 1,203 1,202 1,190 Total NV Energy $ 4,840 $ 4,860 $ 5,118
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) 2015 2014 8.875% Bonds, due 2020 $ 147 $ 162 $ 172 9.25% Bonds, due 2020 295 315 338 3.901% to 4.586% European Investment Bank loans, due 2018 to 2022 398 398 420 7.25% Bonds, due 2022 295 306 324 2.50% Bonds due 2025 221 217 — 2.564% European Investment Bank loans, due 2027 369 368 — 7.25% Bonds, due 2028 273 280 297 4.375% Bonds, due 2032 221 217 229 5.125% Bonds, due 2035 295 291 307 5.125% Bonds, due 2035 221 218 230 Total Northern Powergrid $ 2,735 $ 2,772 $ 2,317 (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 2015 2014 Northern Natural Gas: 5.125% Senior Notes, due 2015 $ — $ — $ 100 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 250 248 247 Total Northern Natural Gas 800 795 894 Kern River: 6.676% Senior Notes, due 2016 — — 165 4.893% Senior Notes, due 2018 245 245 299 Total Kern River 245 245 464 Total BHE Pipeline Group $ 1,045 $ 1,040 $ 1,358
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) 2015 2014 AltaLink Investments, L.P.: Series 09-1 Senior Bonds, 5.207%, due 2016 $ 108 $ 112 $ 136 Series 12-1 Senior Bonds, 3.674%, due 2019 145 151 180 Series 13-1 Senior Bonds, 3.265%, due 2020 145 149 176 Series 15-1 Senior Bonds, 2.244%, due 2022 145 144 — Total AltaLink Investments, L.P. 543 556 492 AltaLink Holdings, L.P. Senior debentures, 10.5%, due 2015 — — 78 ALP: Series 2008-1 Notes, 5.243%, due 2018 145 145 171 Series 2013-2 Notes, 3.621%, due 2020 90 90 108 Series 2012-2 Notes, 2.978%, due 2022 199 198 236 Series 2013-4 Notes, 3.668%, due 2023 361 360 429 Series 2014-1 Notes, 3.399%, due 2024 253 252 300 Series 2006-1 Notes, 5.249%, due 2036 108 108 128 Series 2010-1 Notes, 5.381%, due 2040 90 90 108 Series 2010-2 Notes, 4.872%, due 2040 108 108 128 Series 2011-1 Notes, 4.462%, due 2041 199 198 236 Series 2012-1 Notes, 3.99%, due 2042 379 374 451 Series 2013-3 Notes, 4.922%, due 2043 253 252 300 Series 2014-3 Notes, 4.054%, due 2044 213 212 253 Series 2015-1 Notes, 4.090%, due 2045 253 251 — Series 2013-1 Notes, 4.446%, due 2053 181 180 214 Series 2014-2 Notes, 4.274%, due 2064 94 93 111 Total AltaLink, L.P. 2,926 2,911 3,173 Total BHE Transmission $ 3,469 $ 3,467 $ 3,743 (1) The par values for these debt instruments are denominated in Canadian dollars.
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 2015 2014 Fixed-rate (1) : CE Generation Bonds, 7.416%, due 2018 $ 96 $ 97 $ 125 Salton Sea Funding Corporation Bonds, 7.475%, due 2018 50 51 71 Cordova Funding Corporation Bonds, 8.48% to 9.07%, due 2019 112 113 125 Bishop Hill Holdings Senior Notes, 5.125%, due 2032 104 102 107 Solar Star Funding Senior Notes, 3.950%, due 2035 325 321 — Solar Star Funding Senior Notes, 5.375%, due 2035 1,000 988 987 Topaz Solar Farms Senior Notes, 5.750%, due 2039 826 815 838 Topaz Solar Farms Senior Notes, 4.875%, due 2039 242 239 247 Other 25 25 27 Variable-rate (1) : Pinyon Pines I and II Term Loans, due 2019 (2) 380 378 398 Wailuku Special Purpose Revenue Bonds, 0.12%, due 2021 8 8 9 TX Jumbo Road Term Loan, 3.626%, due 2025 226 219 — Total BHE Renewables $ 3,394 $ 3,356 $ 2,934 (1) Amortizes quarterly or semiannually. (2) The term loans have variable interest rates based on LIBOR plus a spread that varies during the term of the agreement. The weighted average variable interest rate as of December 31, 2015 and 2014 was 2.23% and 1.88% , respectively. The Company has entered into interest rate swaps that fix the interest rate on 75% of the outstanding debt. The weighted average fixed interest rate for the 75% portion is fixed at 3.55% as of December 31, 2015 and 2014 .

Risk Management and Hedging A51

Risk Management and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2015
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, 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 ) As of December 31, 2014 Not designated as hedging contracts: Commodity assets (1) $ 47 $ 66 $ 21 $ 1 $ 135 Commodity liabilities (1) (11 ) — (146 ) (134 ) (291 ) Interest rate assets 4 — — — 4 Interest rate liabilities — — (2 ) (4 ) (6 ) Total 40 66 (127 ) (137 ) (158 ) Designated as hedging contracts: Commodity assets 1 — 5 2 8 Commodity liabilities — — (27 ) (17 ) (44 ) Interest rate assets — 1 — — 1 Interest rate liabilities — — (4 ) — (4 ) Total 1 1 (26 ) (15 ) (39 ) Total derivatives 41 67 (153 ) (152 ) (197 ) Cash collateral receivable — — 56 19 75 Total derivatives - net basis $ 41 $ 67 $ (97 ) $ (133 ) $ (122 ) (1) The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31, 2015 and 2014 , a net regulatory asset of $250 million and $223 million , respectively, was recorded related to the net derivative liability of $186 million and $156 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 2015 2014 2013 Beginning balance $ 223 $ 182 $ 235 NV Energy Transaction — — 47 Changes in fair value recognized in net regulatory assets 128 96 29 Net gains (losses) reclassified to operating revenue 1 (32 ) 8 Net losses reclassified to cost of sales (102 ) (23 ) (137 ) Ending balance $ 250 $ 223 $ 182
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 2015 2014 2013 Beginning balance $ 32 $ 12 $ 32 Changes in fair value recognized in OCI 52 (6 ) (9 ) Net gains reclassified to operating revenue 9 — — Net (losses) gains reclassified to cost of sales (47 ) 26 (11 ) Ending balance $ 46 $ 32 $ 12
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 2015 2014 Electricity purchases Megawatt hours 10 6 Natural gas purchases Decatherms 317 308 Fuel purchases Gallons 11 2 Interest rate swaps US$ 653 443 Mortgage sale commitments, net US$ (312 ) (264 )
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, 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 ) As of December 31, 2014 Not designated as hedging contracts (1) : Commodity assets $ 28 $ — $ 1 $ — $ 29 Commodity liabilities (10 ) — (55 ) (49 ) (114 ) Total 18 — (54 ) (49 ) (85 ) Total derivatives 18 — (54 ) (49 ) (85 ) Cash collateral receivable — — 14 14 28 Total derivatives - net basis $ 18 $ — $ (40 ) $ (35 ) $ (57 ) (1) PacifiCorp's commodity derivatives are generally included in rates and as of December 31, 2015 and 2014 , a regulatory asset of $133 million and $85 million , respectively, was recorded related to the net derivative liability of $136 million and $85 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): 2015 2014 Beginning balance $ 85 $ 55 Changes in fair value recognized in regulatory assets 82 45 Net gains (losses) reclassified to operating revenue 40 (4 ) Net losses reclassified to energy costs (74 ) (11 ) Ending balance $ 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 2015 2014 Electricity purchases (sales) Megawatt hours 1 (1 ) Natural gas purchases Decatherms 111 113 Fuel oil purchases Gallons 11 3
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): Current Other Current Other Assets Assets Liabilities Liabilities - Other - Other - Other - Other Total 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 ) As of December 31, 2014 Not designated as hedging contracts (1) : Commodity assets $ 14 $ 3 $ 19 $ 1 $ 37 Commodity liabilities — — (69 ) (4 ) (73 ) Total 14 3 (50 ) (3 ) (36 ) Designated as hedging contracts: Commodity assets — — 4 2 6 Commodity liabilities — — (27 ) (17 ) (44 ) Total — — (23 ) (15 ) (38 ) Total derivatives 14 3 (73 ) (18 ) (74 ) Cash collateral receivable — — 42 5 47 Total derivatives - net basis $ 14 $ 3 $ (31 ) $ (13 ) $ (27 ) (1) MidAmerican Energy's commodity derivatives not designated as hedging contracts are generally included in regulated rates. Accordingly, as of December 31, 2015 and 2014 , a net regulatory asset of $20 million and $38 million , respectively, was recorded related to the net derivative liability of $26 million and $36 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 MidAmerican Energy'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): 2015 2014 2013 Beginning balance $ 38 $ 10 $ 45 Changes in fair value recognized in net regulatory assets 40 61 5 Net losses reclassified to operating revenue (42 ) (28 ) (1 ) Net losses reclassified to cost of fuel, energy and capacity (1 ) (1 ) (1 ) Net losses reclassified to cost of gas sold (15 ) (4 ) (38 ) Ending balance $ 20 $ 38 $ 10
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): 2015 2014 2013 Nonregulated operating revenue $ 15 $ 6 $ — Regulated cost of fuel, energy and capacity 2 — — Nonregulated cost of sales (21 ) 9 (2 ) Total $ (4 ) $ 15 $ (2 )
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): 2015 2014 2013 Beginning balance $ 34 $ 11 $ 32 Changes in fair value recognized in OCI 58 (3 ) (11 ) Net (losses) gains reclassified to nonregulated cost of sales (47 ) 26 (10 ) Ending balance $ 45 $ 34 $ 11
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 2015 2014 Electricity purchases Megawatt hours 15 14 Natural gas purchases Decatherms 17 19
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, 2015 Commodity liabilities (1) $ (8 ) $ (14 ) $ (22 ) As of December 31, 2014 Commodity liabilities (1) $ (9 ) $ (21 ) $ (30 ) (1) Nevada Power 's commodity derivatives not designated as hedging contracts are included in regulated rates and as of December 31 , 2015 and 2014 , a regulatory asset of $22 million and $30 million , respectively, was recorded related to the derivative liability of $22 million and $30 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 2015 2014 Electricity sales Megawatt hours (2 ) (3 ) Natural gas purchases Decatherms 126 115

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 2015 2014 2013 2015 2014 2013 Beginning balance $ 51 $ 60 $ 32 $ — $ — $ — $ 45 $ 44 $ 41 Changes included in earnings 19 19 34 87 — — — — — Changes in fair value recognized in OCI (7 ) — (2 ) — — — (1 ) 1 3 Changes in fair value recognized in net regulatory assets (19 ) 5 1 — — — — — — Purchases 1 1 4 — — — — — — Settlements 2 1 (9 ) (86 ) — — — — — Transfers from Level 2 — (35 ) — 3 — — — — — Ending balance $ 47 $ 51 $ 60 $ 4 $ — $ — $ 44 $ 45 $ 44
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, 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 ) As of December 31, 2014 Assets: Commodity derivatives $ 1 $ 48 $ 94 $ (40 ) $ 103 Interest rate derivatives — 5 — — 5 Mortgage loans held for sale — 279 — — 279 Money market mutual funds (2) 320 — — — 320 Debt securities: United States government obligations 136 — — — 136 International government obligations — 1 — — 1 Corporate obligations — 39 — — 39 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Auction rate securities — — 45 — 45 Equity securities: United States companies 238 — — — 238 International companies 886 — — — 886 Investment funds 137 — — — 137 $ 1,718 $ 376 $ 139 $ (40 ) $ 2,193 Liabilities: Commodity derivatives $ (18 ) $ (274 ) $ (43 ) $ 115 $ (220 ) Interest rate derivatives — (10 ) — — (10 ) $ (18 ) $ (284 ) $ (43 ) $ 115 $ (230 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $103 million and $75 million as of December 31, 2015 and 2014 , 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): 2015 2014 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 37,972 $ 41,785 $ 38,649 $ 43,863
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, 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) 83 351 — 434 Limited partnership interests (3) — — 65 65 Total $ 527 $ 451 $ 65 $ 1,043 As of December 31, 2014 Cash equivalents $ — $ 8 $ — $ 8 Debt securities: United States government obligations 15 — — 15 Corporate obligations — 53 — 53 Municipal obligations — 8 — 8 Agency, asset and mortgage-backed obligations — 48 — 48 Equity securities: United States companies 488 — — 488 International companies 16 — — 16 Investment funds (2) 217 223 — 440 Limited partnership interests (3) — — 70 70 Total $ 736 $ 340 $ 70 $ 1,146 (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 53% and 47% , respectively, for 2015 and 50% and 50% , respectively, for 2014 , and are invested in United States and international securities of approximately 40% and 60% , respectively, for 2015 and 43% and 57% , respectively, for 2014 . (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, 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) 32 126 — 158 Limited partnership interests (3) — — 4 4 Total $ 144 $ 157 $ 4 $ 305 As of December 31, 2014 Cash and cash equivalents (4) $ 139 $ — $ — $ 139 Debt securities: United States government obligations 8 — — 8 Corporate obligations — 18 — 18 Municipal obligations — 2 — 2 Agency, asset and mortgage-backed obligations — 16 — 16 Equity securities: United States companies 112 — — 112 International companies 4 — — 4 Investment funds (2) 84 94 — 178 Limited partnership interests (3) — — 5 5 Total $ 347 $ 130 $ 5 $ 482 (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 61% and 39% , respectively, for 2015 and 63% and 37% , respectively, for 2014 , and are invested in United States and international securities of approximately 67% and 33% , respectively, for 2015 and 64% and 36% , respectively, for 2014 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. (4) In December 2014, PacifiCorp began to migrate funds to cash and cash equivalents in anticipation of the $150 million to be transferred to a fund managed by the UMWA in May 2015 as a result of the other postretirement settlement. Remaining investments were rebalanced to align to target investment allocations. 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, 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 ) As of December 31, 2014 Assets: Commodity derivatives $ — $ 25 $ 4 $ (11 ) $ 18 Money market mutual funds (2) 30 — — — 30 $ 30 $ 25 $ 4 $ (11 ) $ 48 Liabilities - Commodity derivatives $ — $ (114 ) $ — $ 39 $ (75 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $75 million and $28 million as of December 31, 2015 and 2014 , respectively. (2) Amounts are included in cash and cash equivalents, other current assets and other assets on the Consolidated Balance Sheets. Money market mutual funds are accounted for as available-for-sale securities and the fair value 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): 2015 2014 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 7,114 $ 8,210 $ 6,985 $ 8,358
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, 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) 61 289 — 350 Real estate funds — — 47 47 Total $ 236 $ 395 $ 47 $ 678 As of December 31, 2014 Cash equivalents $ — $ 24 $ — $ 24 Debt securities: United States government obligations 8 — — 8 Corporate obligations — 29 — 29 Municipal obligations — 4 — 4 Agency, asset and mortgage-backed obligations — 33 — 33 Equity securities: United States companies 149 — — 149 International equity securities 40 — — 40 Investment funds (2) 84 319 — 403 Real estate funds — — 40 40 Total $ 281 $ 409 $ 40 $ 730 (1) Refer to Note 13 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 72% and 28% , respectively, for 2015 and 68% and 32% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 73% and 27% , respectively, for 2015 and 74% and 26% , respectively, for 2014 . 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, 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 $ 186 $ 63 $ — $ 249 As of December 31, 2014 Cash equivalents $ 4 $ — $ — $ 4 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 11 — 11 Municipal obligations — 40 — 40 Agency, asset and mortgage-backed obligations — 15 — 15 Equity securities: United States companies 128 — — 128 Investment funds (2) 56 — — 56 Total $ 193 $ 66 $ — $ 259 (1) Refer to Note 13 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 68% and 32% , respectively, for 2015 and 69% and 31% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 32% and 68% , respectively, for 2015 and 31% and 69% , respectively, for 2014 . 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, 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 ) As of December 31, 2014: Assets: Commodity derivatives $ 1 $ 18 $ 24 $ (26 ) $ 17 Money market mutual funds (2) 1 — — — 1 Debt securities: United States government obligations 136 — — — 136 International government obligations — 1 — — 1 Corporate obligations — 39 — — 39 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Auction rate securities — — 26 — 26 Equity securities: United States companies 238 — — — 238 International companies 5 — — — 5 $ 381 $ 62 $ 50 $ (26 ) $ 467 Liabilities - commodity derivatives $ (18 ) $ (87 ) $ (12 ) $ 73 $ (44 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $28 million and $47 million as of December 31, 2015 and 2014 , 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 2015 2014 2013 2015 2014 2013 Beginning balance $ 12 $ (3 ) $ — $ 26 $ 23 $ 21 Changes included in earnings (1) 11 12 3 — — — Changes in fair value recognized in OCI (7 ) — (2 ) — 3 2 Changes in fair value recognized in net regulatory assets (25 ) 6 — — — — Purchases 1 1 — — — — Settlements 2 (4 ) (4 ) — — — Ending balance $ (6 ) $ 12 $ (3 ) $ 26 $ 26 $ 23 (1) Changes included in earnings are reported as nonregulated operating revenue on the Statements of Operations. Net unrealized (losses) gains included in earnings for the years ended December 31, 2015 , 2014 and 2013 , related to commodity derivatives held at December 31, 2015 , 2014 and 2013 , totaled $8 million , $16 million and $(5) 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): 2015 2014 Carrying Value Fair Value Carrying Value Fair Value Long-term debt $ 4,271 $ 4,636 $ 4,056 $ 4,581
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): 2015 2014 Carrying Value Fair Value Carrying Value Fair Value Long-term debt $ 4,597 $ 5,051 $ 4,381 $ 5,012
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, 2015 Assets - investment funds $ 5 $ — $ — $ 5 Liabilities - commodity derivatives $ — $ — $ (22 ) $ (22 ) As of December 31, 2014 Assets - investment funds $ 20 $ — $ — $ 20 Liabilities - commodity derivatives $ — $ — $ (30 ) $ (30 )
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): 2015 2014 Beginning balance $ (30 ) $ (47 ) Changes in fair value recognized in regulatory assets — 9 Purchases — — Settlements 8 8 Ending balance $ (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): 2015 2014 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 2,788 $ 3,240 $ 3,034 $ 3,712
Sierra Pacific Power Company [Member]
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 Sierra Pacific 's long-term debt as of December 31 (in millions): 2015 2014 Carrying Fair Carrying Fair Value Value Value Value Long-term debt $ 1,165 $ 1,248 $ 1,164 $ 1,301

Other, Net (Tables)

Other, Net (Tables)	12 Months Ended
	Dec. 31, 2015
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): 2015 2014 2013 Corporate-owned life insurance income $ 4 $ 8 $ 15 Gains on sales of assets and other investments — — 1 Other, net 1 2 — Total $ 5 $ 10 $ 16
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): 2015 2014 2013 Corporate-owned life insurance income $ 4 $ 8 $ 15 Gains on sales of assets and other investments 13 — 1 Leverage leases 1 5 2 Other, net 1 5 4 Total $ 19 $ 18 $ 22 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, 2015
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): 2015 2014 2013 Current: Federal $ (929 ) $ (1,872 ) $ (985 ) State 29 (3 ) (2 ) Foreign 84 129 121 (816 ) (1,746 ) (866 ) Deferred: Federal 1,310 2,296 1,306 State (53 ) 37 (247 ) Foreign 17 11 (59 ) 1,274 2,344 1,000 Investment tax credits (8 ) (9 ) (4 ) Total $ 450 $ 589 $ 130
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: 2015 2014 2013 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (11 ) (10 ) (14 ) State income tax, net of federal income tax benefit (1 ) 1 (9 ) Income tax effect of foreign income (7 ) (3 ) (6 ) Equity income (loss) 2 2 (1 ) Other, net (2 ) (2 ) 2 Effective income tax rate 16 % 23 % 7 %
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): 2015 2014 Deferred income tax assets: Federal, state and foreign carryforwards $ 865 $ 781 Regulatory liabilities 834 812 AROs 317 249 Employee benefits 190 187 Derivative contracts 83 62 Other 815 781 Total deferred income tax assets 3,104 2,872 Valuation allowances (35 ) (23 ) Total deferred income tax assets, net 3,069 2,849 Deferred income tax liabilities: Property-related items (13,157 ) (11,989 ) Regulatory assets (1,446 ) (1,374 ) Investments (852 ) (699 ) Other (299 ) (301 ) Total deferred income tax liabilities (15,754 ) (14,363 ) Net deferred income tax liability $ (12,685 ) $ (11,514 )
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, 2015 (in millions): Federal State Net operating loss carryforwards (1) $ 185 $ 10,084 Deferred income taxes on net operating loss carryforwards $ 69 $ 589 Expiration dates 2023-2026 2016-2035 Foreign and other tax credits (2) $ 176 $ 31 Expiration dates 2023- indefinite 2016- 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 net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2022. (2) Includes $102 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, 2015 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): 2015 2014 Beginning balance $ 220 $ 211 Additions based on tax positions related to the current year 3 11 Additions for tax positions of prior years 46 48 Reductions for tax positions of prior years (58 ) (50 ) Statute of limitations (6 ) (1 ) Settlements (6 ) — Interest and penalties (1 ) 1 Ending balance $ 198 $ 220
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): 2015 2014 2013 Current: Federal $ 130 $ 2 $ 54 State 26 10 13 Total 156 12 67 Deferred: Federal 148 260 204 State 29 43 29 Total 177 303 233 Investment tax credits (5 ) (6 ) (3 ) Total income tax expense $ 328 $ 309 $ 297
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: 2015 2014 2013 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 ) (7 ) (7 ) Other — — (1 ) Effective income tax rate 32 % 31 % 30 %
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): 2015 2014 Deferred income tax assets: Regulatory liabilities $ 374 $ 362 Employee benefits 189 184 Derivative contracts and unamortized contract values 94 79 State carryforwards 68 68 Loss contingencies 67 70 Asset retirement obligations 81 47 Other 88 92 961 902 Deferred income tax liabilities: Property, plant and equipment (5,030 ) (4,780 ) Regulatory assets (639 ) (647 ) Other (42 ) (56 ) (5,711 ) (5,483 ) Net deferred income tax liability $ (4,750 ) $ (4,581 )
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, 2015 (in millions): State Net operating loss carryforwards $ 1,416 Deferred income taxes on net operating loss carryforwards $ 52 Expiration dates 2016 - 2032 Tax credit carryforwards $ 16 Expiration dates 2016 - 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 consists of the following for the years ended December 31 (in millions): 2015 2014 2013 Current: Federal $ (405 ) $ (401 ) $ (196 ) State (10 ) (3 ) (10 ) (415 ) (404 ) (206 ) Deferred: Federal 281 299 101 State (6 ) 2 3 275 301 104 Investment tax credits (1 ) (1 ) (1 ) Total $ (141 ) $ (104 ) $ (103 )
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 is as follows for the years ended December 31: 2015 2014 2013 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (65 ) (59 ) (70 ) State income tax, net of federal income tax benefit (3 ) — (2 ) Effects of ratemaking (12 ) (8 ) (3 ) Other, net 1 (1 ) (2 ) Effective income tax rate (44 )% (33 )% (42 )%
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): 2015 2014 Deferred income tax assets: Regulatory liabilities $ 327 $ 332 Employee benefits 66 68 Derivative contracts 29 30 Asset retirement obligations 214 185 Other 59 59 Total deferred income tax assets 695 674 Deferred income tax liabilities: Depreciable property (3,321 ) (2,945 ) Regulatory assets (418 ) (366 ) Other (17 ) (25 ) Total deferred income tax liabilities (3,756 ) (3,336 ) Net deferred income tax liability $ (3,061 ) $ (2,662 )
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): 2015 2014 Beginning balance $ 26 $ 29 Additions based on tax positions related to the current year 3 6 Additions for tax positions of prior years 47 38 Reductions based on tax positions related to the current year (6 ) (4 ) Reductions for tax positions of prior years (46 ) (40 ) Statute of limitations (5 ) (3 ) Settlements (6 ) — Interest and penalties (3 ) — Ending balance $ 10 $ 26
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 consists of the following for the years ended December 31 (in millions): 2015 2014 2013 Current: Federal $ (408 ) $ (404 ) $ (200 ) State (12 ) (4 ) (12 ) (420 ) (408 ) (212 ) Deferred: Federal 282 297 100 State (5 ) 2 3 277 299 103 Investment tax credits (1 ) (1 ) (1 ) Total $ (144 ) $ (110 ) $ (110 )
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 is as follows for the years ended December 31: 2015 2014 2013 Federal statutory income tax rate 35 % 35 % 35 % Income tax credits (67 ) (61 ) (75 ) State income tax, net of federal income tax benefit (3 ) (1 ) (3 ) Effects of ratemaking (12 ) (9 ) (3 ) Other, net 1 (1 ) (2 ) Effective income tax rate (46 )% (37 )% (48 )%
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): 2015 2014 Deferred income tax assets: Regulatory liabilities $ 327 $ 332 Employee benefits 66 68 Derivative contracts 29 30 Asset retirement obligations 214 185 Other 68 70 Total deferred income tax assets 704 685 Deferred income tax liabilities: Depreciable property (3,326 ) (2,950 ) Regulatory assets (418 ) (366 ) Other (16 ) (25 ) Total deferred income tax liabilities (3,760 ) (3,341 ) Net deferred income tax liability $ (3,056 ) $ (2,656 )
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): 2015 2014 Beginning balance $ 26 $ 29 Additions based on tax positions related to the current year 4 6 Additions for tax positions of prior years 46 38 Reductions based on tax positions related to the current year (6 ) (4 ) Reductions for tax positions of prior years (46 ) (40 ) Statute of limitations (5 ) (3 ) Settlements (6 ) — Interest and penalties (3 ) — Ending balance $ 10 $ 26
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): 2015 2014 2013 Current – Federal $ — $ — $ (1 ) Deferred – Federal 163 131 96 Investment tax credits (1 ) (1 ) (1 ) Total income tax expense $ 162 $ 130 $ 94
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 : 2015 2014 2013 Federal statutory income tax rate 35 % 35 % 35 % Non-deductible BHE Merger related expenses — — 3 Effects of ratemaking 1 1 1 Effective income tax rate 36 % 36 % 39 %
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): 2015 2014 Deferred income tax assets: Federal net operating loss and credit carryforwards $ 15 $ 158 Capital and financial leases 174 178 Employee benefits 30 22 Regulatory liabilities 47 37 Other 39 57 Total deferred income tax assets 305 452 Valuation allowance (5 ) (2 ) Total deferred income tax assets, net 300 450 Deferred income tax liabilities: Property related items (1,242 ) (1,175 ) Regulatory assets (275 ) (341 ) Capital and financial leases (169 ) (174 ) Other (19 ) (29 ) Total deferred income tax liabilities (1,705 ) (1,719 ) Net deferred income tax liability $ (1,405 ) $ (1,269 )
Summary of Operating Loss Carryforwards [Table Text Block]	The following table provides Nevada Power 's federal net operating loss and tax credit carryforwards and expiration dates as of December 31 , 2015 (in millions): Net operating loss carryforwards $ 4 Deferred income taxes on federal net operating loss carryforwards $ 1 Expiration dates 2031 - 2035 Other tax credits $ 14 Expiration dates 2016 - 2035
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): 2015 2014 2013 Current – Federal $ — $ — $ (2 ) Deferred: Federal 48 48 38 State — — (2 ) Total deferred 48 48 36 Investment tax credits (1 ) (1 ) (1 ) Total income tax expense $ 47 $ 47 $ 33
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 : 2015 2014 2013 Federal statutory income tax rate 35 % 35 % 35 % Non-deductible BHE Merger related expenses — — 1 Effects of ratemaking 1 1 1 Other — (1 ) — Effective income tax rate 36 % 35 % 37 %
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): 2015 2014 Deferred income tax assets: Net operating loss and credit carryforwards $ 39 $ 56 Employee benefit plans 25 22 Regulatory liabilities 19 21 Capital and financial lease liabilities 13 9 Customer Advances 8 7 Other 12 15 Total deferred income tax assets $ 116 $ 130 Deferred income tax liabilities: Property related items $ (538 ) $ (478 ) Regulatory assets (121 ) (147 ) Capital and financial leases (13 ) (9 ) Other (14 ) (20 ) Total deferred income tax liabilities $ (686 ) $ (654 ) Net deferred income tax liability $ (570 ) $ (524 )
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 , 2015 (in millions): Net operating loss carryforwards $ 95 Deferred income taxes on federal net operating loss carryforwards $ 33 Expiration dates 2031 - 2035 Other tax credits $ 5 Expiration dates 2016 - 2035

Supplemental Cash Flow Disclo55

Supplemental Cash Flow Disclosures (Tables)	12 Months Ended
	Dec. 31, 2015
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): 2015 2014 2013 Supplemental disclosure of cash flow information: Interest paid, net of amounts capitalized $ 1,764 $ 1,585 $ 1,073 Income taxes received, net (1) $ 1,666 $ 635 $ 1,105 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 718 $ 1,143 $ 661 (1) Includes $1.8 billion , $764 million and $1.2 billion of income taxes received from Berkshire Hathaway in 2015 , 2014 and 2013 , 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): 2015 2014 2013 Interest paid, net of amounts capitalized $ 342 $ 340 $ 340 Income taxes paid, net $ 40 $ 161 $ 120 Supplemental disclosure of non-cash investing and financing activities: Accounts payable related to property, plant and equipment additions $ 147 $ 140 $ 157 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): 2015 2014 2013 Supplemental cash flow information: Interest paid, net of amounts capitalized $ 154 $ 144 $ 109 Income taxes received, net $ 629 $ 149 $ 36 Supplemental disclosure of non-cash investing transactions: Accounts payable related to utility plant additions $ 249 $ 128 $ 117
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): 2015 2014 2013 Supplemental cash flow information: Interest paid, net of amounts capitalized $ 177 $ 167 $ 132 Income taxes received, net $ 630 $ 153 $ 42 Supplemental disclosure of non-cash investing transactions: Accounts payable related to utility plant additions $ 249 $ 128 $ 117
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): 2015 2014 2013 Supplemental disclosure of cash flow information - Interest paid, net of amounts capitalized $ 186 $ 194 $ 209 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 51 $ 30 $ 25 Capital and financial lease obligations incurred $ (5 ) $ 7 $ 419
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): 2015 2014 2013 Supplemental disclosure of cash flow information - Interest paid, net of amounts capitalized $ 54 $ 54 $ 59 Supplemental disclosure of non-cash investing and financing transactions: Accruals related to property, plant and equipment additions $ 24 $ 31 $ 37 Capital and financial lease obligations incurred $ 13 $ 1 $ 22

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2015
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, 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 ) As of December 31, 2014 Assets: Commodity derivatives $ 1 $ 48 $ 94 $ (40 ) $ 103 Interest rate derivatives — 5 — — 5 Mortgage loans held for sale — 279 — — 279 Money market mutual funds (2) 320 — — — 320 Debt securities: United States government obligations 136 — — — 136 International government obligations — 1 — — 1 Corporate obligations — 39 — — 39 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Auction rate securities — — 45 — 45 Equity securities: United States companies 238 — — — 238 International companies 886 — — — 886 Investment funds 137 — — — 137 $ 1,718 $ 376 $ 139 $ (40 ) $ 2,193 Liabilities: Commodity derivatives $ (18 ) $ (274 ) $ (43 ) $ 115 $ (220 ) Interest rate derivatives — (10 ) — — (10 ) $ (18 ) $ (284 ) $ (43 ) $ 115 $ (230 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $103 million and $75 million as of December 31, 2015 and 2014 , 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.
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 2015 2014 2013 2015 2014 2013 Service cost $ 4 $ 5 $ 6 $ 3 $ 6 $ 9 Interest cost 53 57 54 16 28 25 Expected return on plan assets (77 ) (76 ) (74 ) (23 ) (31 ) (30 ) Net amortization 42 29 48 (4 ) 2 8 Net periodic benefit cost (credit) $ 22 $ 15 $ 34 $ (8 ) $ 5 $ 12
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 2015 2014 2015 2014 Plan assets at fair value, beginning of year $ 1,146 $ 1,171 $ 482 $ 486 Employer contributions 4 10 1 1 Participant contributions — — 6 7 Actual return on plan assets — 53 1 25 Settlement — — (150 ) — Benefits paid (107 ) (88 ) (35 ) (37 ) Plan assets at fair value, end of year $ 1,043 $ 1,146 $ 305 $ 482
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 2015 2014 2015 2014 Benefit obligation, beginning of year $ 1,378 $ 1,230 $ 539 $ 598 Service cost 4 5 3 6 Interest cost 53 57 16 28 Participant contributions — — 6 7 Actuarial (gain) loss (39 ) 174 (17 ) (63 ) Settlement — — (150 ) — Benefits paid (107 ) (88 ) (35 ) (37 ) Benefit obligation, end of year $ 1,289 $ 1,378 $ 362 $ 539 Accumulated benefit obligation, end of year $ 1,289 $ 1,378
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 2015 2014 2015 2014 Plan assets at fair value, end of year $ 1,043 $ 1,146 $ 305 $ 482 Less - Benefit obligation, end of year 1,289 1,378 362 539 Funded status $ (246 ) $ (232 ) $ (57 ) $ (57 ) Amounts recognized on the Consolidated Balance Sheets: Other current liabilities $ (4 ) $ (4 ) $ — $ — Other long-term liabilities (242 ) (228 ) (57 ) (57 ) Amounts recognized $ (246 ) $ (232 ) $ (57 ) $ (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 2015 2014 2015 2014 Net loss $ 508 $ 520 $ 36 $ 41 Prior service credit (13 ) (21 ) (19 ) (26 ) Regulatory deferrals (3 ) (3 ) 9 2 Total $ 492 $ 496 $ 26 $ 17 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2015 and 2014 is as follows (in millions): Accumulated Other Regulatory Comprehensive Asset Loss Total Pension Balance, December 31, 2013 $ 313 $ 15 $ 328 Net loss arising during the year 189 8 197 Net amortization (28 ) (1 ) (29 ) Total 161 7 168 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 Regulatory Asset Other Postretirement Balance, December 31, 2013 $ 77 Net gain arising during the year (58 ) Net amortization (2 ) Total (60 ) Balance, December 31, 2014 17 Net loss arising during the year 5 Net amortization 4 Total 9 Balance, December 31, 2015 $ 26
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 2016 into net periodic benefit cost are estimated to be as follows (in millions): Net Prior Service Regulatory Loss Credit Deferrals Total Pension $ 42 $ (8 ) $ (1 ) $ 33 Other postretirement 1 (7 ) 1 (5 ) Total $ 43 $ (15 ) $ — $ 28
Plan Assumptions [Table Text Block]	Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2015 2014 2013 2015 2014 2013 Benefit obligations as of December 31: Discount rate 4.40 % 4.00 % 4.80 % 4.35 % 3.90 % 4.90 % Rate of compensation increase 2.75 2.75 3.00 N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.00 % 4.80 % 4.05 % 3.99 % 4.90 % 4.10 % Expected return on plan assets 7.50 7.50 7.50 7.08 7.50 7.50 Rate of compensation increase 2.75 3.00 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 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. The assumed healthcare cost trend rates used to determine the benefit obligation as of December 31, 2014 were as follows: Healthcare cost trend rate assumed for next year 8.00 % Rate that the cost trend rate gradually declines to 5.00 % Year that the rate reaches the rate it is assumed to remain at 2025
Expected Benefit Payments [Table Text Block]	The expected benefit payments to participants in PacifiCorp's pension and other postretirement benefit plans for 2016 through 2020 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Pension Other Postretirement 2016 $ 108 $ 28 2017 110 28 2018 108 28 2019 109 27 2020 107 30 2021-2025 448 122
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, 2015 : 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, 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) 83 351 — 434 Limited partnership interests (3) — — 65 65 Total $ 527 $ 451 $ 65 $ 1,043 As of December 31, 2014 Cash equivalents $ — $ 8 $ — $ 8 Debt securities: United States government obligations 15 — — 15 Corporate obligations — 53 — 53 Municipal obligations — 8 — 8 Agency, asset and mortgage-backed obligations — 48 — 48 Equity securities: United States companies 488 — — 488 International companies 16 — — 16 Investment funds (2) 217 223 — 440 Limited partnership interests (3) — — 70 70 Total $ 736 $ 340 $ 70 $ 1,146 (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 53% and 47% , respectively, for 2015 and 50% and 50% , respectively, for 2014 , and are invested in United States and international securities of approximately 40% and 60% , respectively, for 2015 and 43% and 57% , respectively, for 2014 . (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, 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) 32 126 — 158 Limited partnership interests (3) — — 4 4 Total $ 144 $ 157 $ 4 $ 305 As of December 31, 2014 Cash and cash equivalents (4) $ 139 $ — $ — $ 139 Debt securities: United States government obligations 8 — — 8 Corporate obligations — 18 — 18 Municipal obligations — 2 — 2 Agency, asset and mortgage-backed obligations — 16 — 16 Equity securities: United States companies 112 — — 112 International companies 4 — — 4 Investment funds (2) 84 94 — 178 Limited partnership interests (3) — — 5 5 Total $ 347 $ 130 $ 5 $ 482 (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 61% and 39% , respectively, for 2015 and 63% and 37% , respectively, for 2014 , and are invested in United States and international securities of approximately 67% and 33% , respectively, for 2015 and 64% and 36% , respectively, for 2014 . (3) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital. (4) In December 2014, PacifiCorp began to migrate funds to cash and cash equivalents in anticipation of the $150 million to be transferred to a fund managed by the UMWA in May 2015 as a result of the other postretirement settlement. Remaining investments were rebalanced to align to target investment allocations. 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, 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 ) As of December 31, 2014 Assets: Commodity derivatives $ — $ 25 $ 4 $ (11 ) $ 18 Money market mutual funds (2) 30 — — — 30 $ 30 $ 25 $ 4 $ (11 ) $ 48 Liabilities - Commodity derivatives $ — $ (114 ) $ — $ 39 $ (75 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $75 million and $28 million as of December 31, 2015 and 2014 , respectively. (2) Amounts are included in cash and cash equivalents, other current assets and other assets on the Consolidated Balance Sheets. Money market mutual funds are accounted for as available-for-sale securities and the fair value approximates cost.
Level Three Defined Benefit Plan Assets Roll Forward [Table Text Block]	The following table reconciles the beginning and ending balances of PacifiCorp's plan assets measured at fair value using significant Level 3 inputs for the years ended December 31 (in millions): Limited Partnership Interests Pension Other Postretirement Balance, December 31, 2012 $ 96 $ 7 Actual return on plan assets still held at December 31, 2013 16 1 Purchases, sales, distributions and settlements (26 ) (2 ) Balance, December 31, 2013 86 6 Actual return on plan assets still held at December 31, 2014 (1 ) — Purchases, sales, distributions and settlements (15 ) (1 ) Balance, December 31, 2014 70 5 Actual return on plan assets still held at December 31, 2015 5 — Purchases, sales, distributions and settlements (10 ) (1 ) Balance, December 31, 2015 $ 65 $ 4
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 2015 2014 2013 Funding improvement plan Surcharge imposed under PPA (1) 2015 2014 2013 Year contributions to plan exceeded more than 5% of total contributions (2) UMWA 1974 Pension Plan 52-1050282 Critical and Declining Critical Seriously Endangered Implemented Yes $ 1 $ 2 $ 3 None Local 57 Trust Fund 87-0640888 At least 80% At least 80% At least 80% None None $ 8 $ 9 $ 9 2014, 2013, 2012 (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, 2013 and 2012. Information for the plan years beginning July 1, 2015 and 2014 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 2015 2014 2013 2015 2014 2013 Service cost $ 12 $ 14 $ 18 $ 7 $ 6 $ 5 Interest cost 32 35 33 9 10 8 Expected return on plan assets (46 ) (45 ) (45 ) (15 ) (15 ) (13 ) Net amortization 2 1 11 (3 ) (3 ) (3 ) Net periodic benefit cost (credit) $ — $ 5 $ 17 $ (2 ) $ (2 ) $ (3 )
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 2015 2014 2015 2014 Plan assets at fair value, beginning of year $ 730 $ 722 $ 259 $ 256 Employer contributions 7 7 1 1 Participant contributions — — 1 1 Actual return on plan assets 4 52 — 13 Benefits paid (63 ) (51 ) (12 ) (12 ) Plan assets at fair value, end of year $ 678 $ 730 $ 249 $ 259
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 2015 2014 2015 2014 Benefit obligation, beginning of year $ 840 $ 768 $ 249 $ 235 Service cost 12 14 7 6 Interest cost 32 35 9 10 Participant contributions — — 1 1 Actuarial (gain) loss (36 ) 74 (20 ) 9 Benefits paid (63 ) (51 ) (12 ) (12 ) Benefit obligation, end of year $ 785 $ 840 $ 234 $ 249 Accumulated benefit obligation, end of year $ 773 $ 825
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 2015 2014 2015 2014 Plan assets at fair value, end of year $ 678 $ 730 $ 249 $ 259 Less - Benefit obligation, end of year 785 840 234 249 Funded status $ (107 ) $ (110 ) $ 15 $ 10 Amounts recognized on the Balance Sheets: Other assets $ 7 $ 12 $ 15 $ 10 Other current liabilities (8 ) (8 ) — — Other liabilities (106 ) (114 ) — — Amounts recognized $ (107 ) $ (110 ) $ 15 $ 10
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 2015 2014 2015 2014 Net loss $ 26 $ 21 $ 42 $ 49 Prior service cost (credit) 2 3 (36 ) (42 ) Total $ 28 $ 24 $ 6 $ 7 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2015 and 2014 is as follows (in millions): Regulatory Asset Regulatory Liability Receivables (Payables) with Affiliates Total Pension Balance, December 31, 2013 $ 16 $ (55 ) $ (2 ) $ (41 ) Net loss arising during the year 6 51 9 66 Net amortization — (1 ) — (1 ) Total 6 50 9 65 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 Regulatory Asset Regulatory Liability Receivables (Payables) with Affiliates Total Other Postretirement Balance, December 31, 2013 $ 10 $ — $ (16 ) $ (6 ) Net loss arising during the year 8 — 2 10 Net amortization 2 — 1 3 Total 10 — 3 13 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
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 2016 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 2015 2014 2013 2015 2014 2013 Benefit obligations as of December 31: Discount rate 4.50 % 4.00 % 4.75 % 4.25 % 3.75 % 4.50 % Rate of compensation increase 2.75 % 2.75 % 3.00 % N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.00 % 4.75 % 4.00 % 3.75 % 4.50 % 3.75 % Expected return on plan assets (1) 7.25 % 7.50 % 7.50 % 7.00 % 7.25 % 7.25 % Rate of compensation increase 2.75 % 3.00 % 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 5.18% for 2015 , and 5.37% for 2014 , and 5.56% for 2013 . 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. 2015 2014 Assumed healthcare cost trend rates as of December 31: Healthcare cost trend rate assumed for next year 7.70 % 8.00 % 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, 2015 $ 1 $ — Other postretirement benefit obligation as of December 31, 2015 3 (3 )
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 2016 through 2020 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Pension Other Postretirement 2016 $ 59 $ 17 2017 60 19 2018 60 20 2019 60 21 2020 61 21 2021-2025 291 102
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, 2015 : 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, 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) 61 289 — 350 Real estate funds — — 47 47 Total $ 236 $ 395 $ 47 $ 678 As of December 31, 2014 Cash equivalents $ — $ 24 $ — $ 24 Debt securities: United States government obligations 8 — — 8 Corporate obligations — 29 — 29 Municipal obligations — 4 — 4 Agency, asset and mortgage-backed obligations — 33 — 33 Equity securities: United States companies 149 — — 149 International equity securities 40 — — 40 Investment funds (2) 84 319 — 403 Real estate funds — — 40 40 Total $ 281 $ 409 $ 40 $ 730 (1) Refer to Note 13 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 72% and 28% , respectively, for 2015 and 68% and 32% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 73% and 27% , respectively, for 2015 and 74% and 26% , respectively, for 2014 . 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, 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 $ 186 $ 63 $ — $ 249 As of December 31, 2014 Cash equivalents $ 4 $ — $ — $ 4 Debt securities: United States government obligations 5 — — 5 Corporate obligations — 11 — 11 Municipal obligations — 40 — 40 Agency, asset and mortgage-backed obligations — 15 — 15 Equity securities: United States companies 128 — — 128 Investment funds (2) 56 — — 56 Total $ 193 $ 66 $ — $ 259 (1) Refer to Note 13 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 68% and 32% , respectively, for 2015 and 69% and 31% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 32% and 68% , respectively, for 2015 and 31% and 69% , respectively, for 2014 . 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, 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 ) As of December 31, 2014: Assets: Commodity derivatives $ 1 $ 18 $ 24 $ (26 ) $ 17 Money market mutual funds (2) 1 — — — 1 Debt securities: United States government obligations 136 — — — 136 International government obligations — 1 — — 1 Corporate obligations — 39 — — 39 Municipal obligations — 2 — — 2 Agency, asset and mortgage-backed obligations — 2 — — 2 Auction rate securities — — 26 — 26 Equity securities: United States companies 238 — — — 238 International companies 5 — — — 5 $ 381 $ 62 $ 50 $ (26 ) $ 467 Liabilities - commodity derivatives $ (18 ) $ (87 ) $ (12 ) $ 73 $ (44 ) (1) Represents netting under master netting arrangements and a net cash collateral receivable of $28 million and $47 million as of December 31, 2015 and 2014 , 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.
Level Three Defined Benefit Plan Assets Roll Forward [Table Text Block]	The following table reconciles the beginning and ending balances of MidAmerican Energy's pension plan assets measured at fair value using significant Level 3 inputs for the years ended December 31, (in millions): Real Estate Funds 2015 2014 2013 Beginning balance $ 40 $ 31 $ 26 Actual return on plan assets still held at period end 7 4 5 Purchases and sales — 5 — Ending balance $ 47 $ 40 $ 31
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): 2015 2014 2013 Pension costs $ 4 $ 4 $ 6 Other postretirement costs (2 ) (2 ) (2 )
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 2015 2014 2013 2015 2014 2013 Service cost $ 33 $ 36 $ 24 $ 11 $ 14 $ 14 Interest cost 121 131 87 31 46 33 Expected return on plan assets (169 ) (164 ) (119 ) (45 ) (53 ) (44 ) Net amortization 53 44 58 (11 ) (3 ) 6 Net periodic benefit cost (credit) $ 38 $ 47 $ 50 $ (14 ) $ 4 $ 9
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 2015 2014 2015 2014 Plan assets at fair value, beginning of year $ 2,718 $ 2,711 $ 858 $ 852 Employer contributions 13 37 2 2 Participant contributions — — 9 11 Actual return on plan assets (17 ) 188 — 54 Settlement (23 ) — (150 ) — Benefits paid (202 ) (218 ) (57 ) (61 ) Plan assets at fair value, end of year $ 2,489 $ 2,718 $ 662 $ 858
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 2015 2014 2015 2014 Benefit obligation, beginning of year $ 3,119 $ 2,821 $ 936 $ 987 Service cost 33 36 11 14 Interest cost 121 131 31 46 Participant contributions — — 9 11 Actuarial loss (gain) (110 ) 349 (43 ) (61 ) Amendment (4 ) — 3 — Settlement (23 ) — (150 ) — Benefits paid (202 ) (218 ) (57 ) (61 ) Benefit obligation, end of year $ 2,934 $ 3,119 $ 740 $ 936 Accumulated benefit obligation, end of year $ 2,906 $ 3,086
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 2015 2014 2015 2014 Fair value of plan assets $ 1,811 $ 1,987 $ 413 $ 598 Projected benefit obligation $ 2,263 $ 2,401 $ 505 $ 686 Accumulated benefit obligation $ 2,244 $ 2,380 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 2015 2014 2015 2014 Plan assets at fair value, end of year $ 2,489 $ 2,718 $ 662 $ 858 Benefit obligation, end of year 2,934 3,119 740 936 Funded status $ (445 ) $ (401 ) $ (78 ) $ (78 ) Amounts recognized on the Consolidated Balance Sheets: Other assets $ 7 $ 12 $ 15 $ 10 Other current liabilities (15 ) (14 ) — — Other long-term liabilities (437 ) (399 ) (93 ) (88 ) Amounts recognized $ (445 ) $ (401 ) $ (78 ) $ (78 )
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 2015 2014 2015 2014 Net loss $ 768 $ 757 $ 97 $ 108 Prior service credit (25 ) (31 ) (68 ) (87 ) Regulatory deferrals (2 ) (3 ) 8 2 Total $ 741 $ 723 $ 37 $ 23 A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2015 and 2014 is as follows (in millions): Accumulated Other Regulatory Regulatory Comprehensive Asset Liability Loss Total Pension Balance, December 31, 2013 $ 490 $ (58 ) $ 9 $ 441 Net loss arising during the year 258 52 16 326 Net amortization (38 ) — (6 ) (44 ) Total 220 52 10 282 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 Regulatory Regulatory Asset Liability Total Other Postretirement Balance, December 31, 2013 $ 99 $ (16 ) $ 83 Net (gain) loss arising during the year (64 ) 1 (63 ) Net amortization 2 1 3 Total (62 ) 2 (60 ) 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
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 2016 into net periodic benefit cost are estimated to be as follows (in millions): Net Prior Service Regulatory Loss Credit Deferrals Total Pension $ 58 $ (11 ) $ (1 ) $ 46 Other postretirement 3 (16 ) 1 (12 ) Total $ 61 $ (27 ) $ — $ 34
Plan Assumptions [Table Text Block]	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. 2015 2014 Assumed healthcare cost trend rates as of December 31: Healthcare cost trend rate assumed for next year 7.70 % 8.00 % 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 Weighted-average assumptions used to determine benefit obligations and net periodic benefit cost were as follows: Pension Other Postretirement 2015 2014 2013 2015 2014 2013 Benefit obligations as of December 31: Discount rate 4.43 % 4.00 % 4.81 % 4.33 % 3.88 % 4.82 % Rate of compensation increase 2.75 % 2.75 % 3.00 % N/A N/A N/A Net periodic benefit cost for the years ended December 31: Discount rate 4.00 % 4.81 % 4.03 % 3.93 % 4.82 % 4.01 % Expected return on plan assets 6.88 % 6.86 % 7.50 % 7.00 % 7.34 % 7.44 % Rate of compensation increase 2.75 % 3.00 % 3.00 % N/A N/A N/A
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, 2015 $ 1 $ (1 ) Other postretirement benefit obligation as of December 31, 2015 5 (5 )
Expected Benefit Payments [Table Text Block]	The expected benefit payments to participants in the Company's pension and other postretirement benefit plans for 2016 through 2020 and for the five years thereafter are summarized below (in millions): Projected Benefit Payments Other Pension Postretirement 2016 $ 221 $ 56 2017 224 57 2018 226 58 2019 224 58 2020 225 61 2021-2025 1,054 272
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, 2015 : 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, 2015 Cash equivalents $ — $ 31 $ — $ 31 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) 144 821 — 965 Limited partnership interests (3) — — 65 65 Real estate funds — — 47 47 Total $ 1,007 $ 1,370 $ 112 $ 2,489 As of December 31, 2014 Cash equivalents $ 15 $ 54 $ — $ 69 Debt securities: United States government obligations 166 — — 166 International government obligations — 11 — 11 Corporate obligations — 268 — 268 Municipal obligations — 27 — 27 Agency, asset and mortgage-backed obligations — 94 — 94 Equity securities: United States companies 698 — — 698 International companies 122 — — 122 Investment funds (2) 301 852 — 1,153 Limited partnership interests (3) — — 70 70 Real estate funds — — 40 40 Total $ 1,302 $ 1,306 $ 110 $ 2,718 (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 66% and 34% , respectively, for 2015 and 61% and 39% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 58% and 42% , respectively, for 2015 and 64% and 36% , respectively, for 2014 . (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, 2015 Cash equivalents (2) $ 12 $ 2 $ — $ 14 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 (3) 149 153 — 302 Limited partnership interests (4) — — 4 4 Total $ 401 $ 257 $ 4 $ 662 As of December 31, 2014 Cash equivalents $ 145 $ 1 $ — $ 146 Debt securities: United States government obligations 17 — — 17 Corporate obligations — 34 — 34 Municipal obligations — 43 — 43 Agency, asset and mortgage-backed obligations — 31 — 31 Equity securities: United States companies 243 — — 243 International companies 6 — — 6 Investment funds (3) 202 131 — 333 Limited partnership interests (4) — — 5 5 Total $ 613 $ 240 $ 5 $ 858 (1) Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy. (2) In December 2014, PacifiCorp began to migrate funds to cash and cash equivalents in anticipation of the $150 million to be transferred to a fund managed by the UMWA in May 2015 as a result of the other postretirement settlement. Remaining investments were rebalanced to align to PacifiCorp's target investment allocations. (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 2015 and 63% and 37% , respectively, for 2014 . Additionally, these funds are invested in United States and international securities of approximately 70% and 30% , respectively, for 2015 and 69% and 31% , respectively, for 2014 . (4) Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
Level Three Defined Benefit Plan Assets Roll Forward [Table Text Block]	The following table reconciles the beginning and ending balances of the Company's plan assets measured at fair value using significant Level 3 inputs for the years ended December 31 (in millions): Other Pension Postretirement- Limited Real Limited Partnership Estate Partnership Interests Funds Interests Balance, December 31, 2012 $ 96 $ 26 $ 7 Actual return on plan assets still held at period end 16 5 1 Purchases, sales, distributions and settlements (26 ) — (2 ) Balance, December 31, 2013 86 31 6 Actual return on plan assets still held at period end (1 ) 4 — Purchases, sales, distributions and settlements (15 ) 5 (1 ) Balance, December 31, 2014 70 40 5 Actual return on plan assets still held at period end 5 7 — Purchases, sales, distributions and settlements (10 ) — (1 ) Balance, December 31, 2015 $ 65 $ 47 $ 4
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): 2015 2014 2013 Service cost $ 24 $ 24 $ 22 Interest cost 79 95 85 Expected return on plan assets (116 ) (124 ) (101 ) Net amortization 62 51 53 Net periodic benefit cost $ 49 $ 46 $ 59
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): 2015 2014 Plan assets at fair value, beginning of year $ 2,368 $ 2,177 Employer contributions 77 89 Participant contributions 2 2 Actual return on plan assets 48 337 Benefits paid (91 ) (92 ) Foreign currency exchange rate changes (128 ) (145 ) Plan assets at fair value, end of year $ 2,276 $ 2,368
Changes in Projected Benefit Obligations [Table Text Block]	The following table is a reconciliation of the benefit obligation for the years ended December 31 (in millions): 2015 2014 Benefit obligation, beginning of year $ 2,279 $ 2,185 Service cost 24 24 Interest cost 79 95 Participant contributions 2 2 Actuarial (gain) loss (30 ) 205 Benefits paid (91 ) (92 ) Foreign currency exchange rate changes (121 ) (140 ) Benefit obligation, end of year $ 2,142 $ 2,279 Accumulated benefit obligation, end of year $ 1,891 $ 2,019
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): 2015 2014 Plan assets at fair value, end of year $ 2,276 $ 2,368 Benefit obligation, end of year 2,142 2,279 Funded status $ 134 $ 89 Amounts recognized on the Consolidated Balance Sheets: Other assets $ 134 $ 89
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): 2015 2014 Balance, beginning of year $ 655 $ 751 Net loss (gain) arising during the year 38 (8 ) Net amortization (62 ) (51 ) Foreign currency exchange rate changes (39 ) (37 ) Total (63 ) (96 ) Balance, end of year $ 592 $ 655 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): 2015 2014 Net loss $ 592 $ 655
Plan Assumptions [Table Text Block]	Assumptions used to determine benefit obligations and net periodic benefit cost were as follows: 2015 2014 2013 Benefit obligations as of December 31: Discount rate 3.70 % 3.60 % 4.40 % Rate of compensation increase 2.90 % 2.80 % 3.15 % Rate of future price inflation 2.90 % 2.80 % 3.15 % Net periodic benefit cost for the years ended December 31: Discount rate 3.60 % 4.40 % 4.40 % Expected return on plan assets 5.60 % 6.10 % 5.70 % Rate of compensation increase 2.80 % 3.15 % 2.80 % Rate of future price inflation 2.80 % 3.15 % 2.80 %
Expected Benefit Payments [Table Text Block]	Employer contributions to the UK Plan are expected to be £40 million during 2016 . The expected benefit payments to participants in the UK Plan for 2016 through 2020 and for the five years thereafter, using the foreign currency exchange rate as of December 31, 2015 , are summarized below (in millions): 2016 $ 88 2017 90 2018 92 2019 95 2020 97 2021-2025 522
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, 2015 : % 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 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, 2015 Cash equivalents $ 46 $ — $ — $ 46 Debt securities: United Kingdom government obligations 424 — — 424 Other international government obligations — 13 — 13 Corporate obligations — 186 — 186 Investment funds (2) 109 1,294 — 1,403 Real estate funds — — 204 204 Total $ 579 $ 1,493 $ 204 $ 2,276 As of December 31, 2014 Cash equivalents $ 43 $ — $ — $ 43 Debt securities: United States government obligations — — — — United Kingdom government obligations 452 — — 452 Other international government obligations — 14 — 14 Corporate obligations — 196 — 196 Investment funds (2) 114 1,350 — 1,464 Real estate funds — — 199 199 Total $ 609 $ 1,560 $ 199 $ 2,368 (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% for both 2015 and 2014 .
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 2015 2014 2013 Beginning balance $ 199 $ 179 $ 163 Actual return on plan assets still held at period end 18 33 12 Foreign currency exchange rate changes (13 ) (13 ) 4 Ending balance $ 204 $ 199 $ 179

Retirement Plan and Postretir57

Retirement Plan and Postretirement Benefits Retirement Plan and Postretirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2015
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): 2015 2014 Qualified Pension Plan - Other long-term liabilities $ (38 ) $ (23 ) Non-Qualified Pension Plans: Other current liabilities (1 ) (1 ) Other long-term liabilities (9 ) (9 ) Other Postretirement Plans - Other long-term liabilities (5 ) 1
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): 2015 2014 Qualified Pension Plan - Other long-term liabilities $ (29 ) $ (13 ) Non-Qualified Pension Plans: Other current liabilities (1 ) (1 ) Other long-term liabilities (9 ) (10 ) Other Postretirement Plans - Other long-term liabilities (32 ) (33 )
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 2015 2014 2013 2015 2014 2013 Service cost $ 33 $ 36 $ 24 $ 11 $ 14 $ 14 Interest cost 121 131 87 31 46 33 Expected return on plan assets (169 ) (164 ) (119 ) (45 ) (53 ) (44 ) Net amortization 53 44 58 (11 ) (3 ) 6 Net periodic benefit cost (credit) $ 38 $ 47 $ 50 $ (14 ) $ 4 $ 9

Asset Retirement Oblilgations (

Asset Retirement Oblilgations (Tables)	12 Months Ended
	Dec. 31, 2015
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): 2015 2014 Fossil fuel facilities $ 443 $ 334 Quad Cities Station 289 265 Wind generating facilities 104 75 Offshore pipeline facilities 31 31 Solar generating facilities 12 9 Other 42 39 Total asset retirement obligations $ 921 $ 753 Quad Cities Station nuclear decommissioning trust funds $ 429 $ 424
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): 2015 2014 Beginning balance $ 753 $ 696 Acquisitions — 12 Change in estimated costs 104 3 Additions 59 15 Retirements (32 ) (8 ) Accretion 37 35 Ending balance $ 921 $ 753 Reflected as: Other current liabilities $ 92 $ 66 Other long-term liabilities 829 687 Total ARO liability $ 921 $ 753
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): 2015 2014 Beginning balance $ 135 $ 138 Change in estimated costs 62 (3 ) Additions 30 — Retirements (10 ) (6 ) Accretion 7 6 Ending balance $ 224 $ 135 Reflected as: Other current liabilities $ 35 $ 21 Other long-term liabilities 189 114 $ 224 $ 135
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): 2015 2014 Quad Cities Station $ 289 $ 265 Fossil-fueled generating facilities 160 132 Wind-powered generating facilities 82 60 Other 1 3 Total asset retirement obligations $ 532 $ 460 Quad Cities Station nuclear decommissioning trust funds (1) $ 429 $ 424 (1) Refer to Note 6 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): 2015 2014 Beginning balance $ 460 $ 430 Change in estimated costs 36 (2 ) Additions 22 11 Retirements (9 ) — Accretion 23 21 Ending balance $ 532 $ 460 Reflected as: Other current liabilities $ 44 $ 28 Asset retirement obligations 488 432 $ 532 $ 460
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): 2015 2014 Waste water remediation $ 42 $ 53 Evaporative ponds and dry ash landfills 27 25 Asbestos 3 3 Other 13 5 Total asset retirement obligations $ 85 $ 86
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): 2015 2014 Beginning balance $ 86 $ 100 Change in estimated costs 3 (18 ) Additions 3 — Retirements (11 ) — Accretion 4 4 Ending balance $ 85 $ 86 Reflected as: Other current liabilities $ 13 $ 14 Other long-term liabilities 72 72 $ 85 $ 86
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): 2015 2014 Asbestos $ 4 $ 5 Evaporative ponds and dry ash landfills 3 2 Other 3 4 Total asset retirement obligations $ 10 $ 11
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): 2015 2014 Beginning balance $ 11 $ 16 Change in estimated costs — (6 ) Retirements (1 ) — Accretion — 1 Ending balance $ 10 $ 11 Reflected as: Other current liabilities $ — $ 3 Other long-term liabilities 10 8 $ 10 $ 11

Commitments and Contingencies59

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 are as follows (in millions): 2021 and 2016 2017 2018 2019 2020 Thereafter Total Contract type: Fuel, capacity and transmission contract commitments $ 2,214 $ 1,760 $ 1,345 $ 1,229 $ 1,129 $ 9,494 $ 17,171 Construction commitments 1,544 25 11 3 3 5 1,591 Operating leases and easements 143 118 95 77 66 1,007 1,506 Maintenance, service and other contracts 181 264 180 188 156 805 1,774 $ 4,082 $ 2,167 $ 1,631 $ 1,497 $ 1,354 $ 11,311 $ 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, 2015 are as follows (in millions): 2016 2017 2018 2019 2020 2021 and Thereafter Total Contract type: Purchased electricity contracts - commercially operable $ 168 $ 71 $ 70 $ 67 $ 68 $ 401 $ 845 Purchased electricity contracts - non-commercially operable 16 102 104 104 104 1,687 2,117 Fuel contracts 862 689 558 542 496 1,720 4,867 Construction commitments 144 12 10 2 2 5 175 Transmission 105 97 91 76 55 508 932 Operating leases and easements 5 4 4 4 4 42 63 Maintenance, service and other contracts 36 30 19 24 11 74 194 Total commitments $ 1,336 $ 1,005 $ 856 $ 819 $ 740 $ 4,437 $ 9,193
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, 2015 , are as follows (in millions): 2021 and 2016 2017 2018 2019 2020 Thereafter Total Contract type: Coal and natural gas for generation $ 173 $ 113 $ 72 $ 29 $ — $ — $ 387 Electric capacity and transmission 30 30 11 10 10 58 149 Natural gas contracts for gas operations 131 69 31 11 10 30 282 Construction commitments 535 10 — — — — 545 Easements and operating leases 17 17 17 16 15 516 598 Maintenance and services contracts 47 59 71 73 73 265 588 $ 933 $ 298 $ 202 $ 139 $ 108 $ 869 $ 2,549
Nevada Power Company [Member]
Contractual Obligation [Line Items]
Contractual Obligation, Fiscal Year Maturity Schedule	has the following firm commitments that are not reflected on the Consolidated Balance Sheet. Minimum payments as of December 31 , 2015 are as follows (in millions): 2016 2017 2018 2019 2020 2021 and Thereafter Total Contract type: Fuel and capacity contract commitments $ 612 $ 478 $ 330 $ 328 $ 330 $ 4,587 $ 6,665 Fuel and capacity contract commitments (not commercially operable) — 20 23 23 30 603 699 Operating leases and easements 11 8 8 7 7 67 108 Maintenance, service and other contracts 46 116 38 37 35 109 381 Total commitments $ 669 $ 622 $ 399 $ 395 $ 402 $ 5,366 $ 7,853
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 , 2015 are as follows (in millions): 2021 and 2016 2017 2018 2019 2020 Thereafter Total Contract type: Fuel and capacity contract commitments $ 207 $ 159 $ 109 $ 88 $ 75 $ 444 $ 1,082 Operating leases and easements 6 4 3 3 3 65 84 Maintenance, service and other contracts 5 4 4 5 5 22 45 Total commitments $ 218 $ 167 $ 116 $ 96 $ 83 $ 531 $ 1,211

Components of Accumulated Oth60

Components of Accumulated Other Comprehensive Loss, Net (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2012 $ (575 ) $ (172 ) $ 261 $ 23 $ (463 ) Other comprehensive income 16 74 263 13 366 Balance, December 31, 2013 (559 ) (98 ) 524 36 (97 ) Other comprehensive income (loss) 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 )
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, 2015 and 2014 (in millions): Unrealized Unrealized Accumulated Losses on Losses Other Available-For-Sale on Cash Flow Comprehensive Securities Hedges Loss, Net Balance, December 31, 2013 $ (4 ) $ (7 ) $ (11 ) Other comprehensive income (loss) 1 (13 ) (12 ) Balance, December 31, 2014 $ (3 ) $ (20 ) $ (23 ) Other comprehensive income (loss) — (7 ) (7 ) Balance, December 31, 2015 $ (3 ) $ (27 ) $ (30 )

Noncontrolling Interests Noncon

Noncontrolling Interests Noncontrolling Interests (Tables)	12 Months Ended
	Dec. 31, 2015
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): 2015 2014 2013 Corporate-owned life insurance income $ 4 $ 8 $ 15 Gains on sales of assets and other investments 13 — 1 Leverage leases 1 5 2 Other, net 1 5 4 Total $ 19 $ 18 $ 22 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, 2015
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, 2015 2014 2013 Operating revenue: PacifiCorp $ 5,232 $ 5,252 $ 5,147 MidAmerican Funding 3,420 3,762 3,413 NV Energy 3,351 3,241 (20 ) Northern Powergrid 1,140 1,283 1,025 BHE Pipeline Group 1,016 1,078 952 BHE Transmission 592 62 — BHE Renewables 728 623 355 HomeServices 2,526 2,144 1,809 BHE and Other (1) (125 ) (119 ) (46 ) Total operating revenue $ 17,880 $ 17,326 $ 12,635 Depreciation and amortization: PacifiCorp $ 780 $ 745 $ 692 MidAmerican Funding 407 351 403 NV Energy 410 379 — Northern Powergrid 202 198 180 BHE Pipeline Group 204 196 190 BHE Transmission 185 13 — BHE Renewables 216 152 71 HomeServices 29 29 33 BHE and Other (1) (5 ) (6 ) (9 ) Total depreciation and amortization $ 2,428 $ 2,057 $ 1,560 Operating income: PacifiCorp $ 1,344 $ 1,308 $ 1,275 MidAmerican Funding 473 423 357 NV Energy 812 791 (42 ) Northern Powergrid 593 674 501 BHE Pipeline Group 464 439 446 BHE Transmission 260 16 (5 ) BHE Renewables 255 314 223 HomeServices 184 125 129 BHE and Other (1) (57 ) (44 ) (49 ) Total operating income 4,328 4,046 2,835 Interest expense (1,904 ) (1,711 ) (1,222 ) Capitalized interest 74 89 84 Allowance for equity funds 91 98 78 Interest and dividend income 107 38 15 Other, net 39 42 51 Total income before income tax expense and equity income (loss) $ 2,735 $ 2,602 $ 1,841 Years Ended December 31, 2015 2014 2013 Interest expense: PacifiCorp $ 383 $ 386 $ 390 MidAmerican Funding 206 197 174 NV Energy 262 283 — Northern Powergrid 145 151 141 BHE Pipeline Group 66 76 80 BHE Transmission 146 14 — BHE Renewables 193 175 138 HomeServices 3 4 3 BHE and Other (1) 500 425 296 Total interest expense $ 1,904 $ 1,711 $ 1,222 Income tax expense (benefit): PacifiCorp $ 328 $ 310 $ 298 MidAmerican Funding (144 ) (110 ) (110 ) NV Energy 207 195 (15 ) Northern Powergrid 35 110 23 BHE Pipeline Group 158 149 149 BHE Transmission 63 28 10 BHE Renewables 41 65 57 HomeServices 72 44 48 BHE and Other (1) (310 ) (202 ) (330 ) Total income tax expense (benefit) $ 450 $ 589 $ 130 Capital expenditures: PacifiCorp $ 916 $ 1,066 $ 1,065 MidAmerican Funding 1,448 1,527 1,027 NV Energy 571 558 — Northern Powergrid 674 675 675 BHE Pipeline Group 240 257 177 BHE Transmission 966 222 — BHE Renewables 1,034 2,221 1,329 HomeServices 16 17 21 BHE and Other 10 12 13 Total capital expenditures $ 5,875 $ 6,555 $ 4,307 As of December 31, 2015 2014 2013 Property, plant and equipment, net: PacifiCorp $ 19,039 $ 18,755 $ 18,563 MidAmerican Funding 11,737 10,535 9,353 NV Energy 9,767 9,648 9,623 Northern Powergrid 5,790 5,599 5,476 BHE Pipeline Group 4,345 4,286 4,147 BHE Transmission 5,301 5,567 — BHE Renewables 4,805 4,897 3,020 HomeServices 70 68 61 BHE and Other (85 ) (107 ) (124 ) Total property, plant and equipment, net $ 60,769 $ 59,248 $ 50,119 Total assets: PacifiCorp $ 23,550 $ 23,404 $ 22,781 MidAmerican Funding 16,499 15,346 13,970 NV Energy 14,656 14,256 14,016 Northern Powergrid 7,317 7,059 6,852 BHE Pipeline Group 4,953 4,951 4,891 BHE Transmission 7,553 7,979 465 BHE Renewables 5,892 6,082 3,832 HomeServices 1,705 1,622 1,375 BHE and Other 1,493 1,117 1,409 Total assets $ 83,618 $ 81,816 $ 69,591 Years Ended December 31, 2015 2014 2013 Operating revenue by country: United States $ 16,121 $ 15,857 $ 11,465 United Kingdom 1,140 1,281 1,023 Canada 600 78 16 Philippines and other 19 110 131 Total operating revenue by country $ 17,880 $ 17,326 $ 12,635 Income before income tax expense and equity income (loss) by country: United States $ 2,034 $ 2,001 $ 1,388 United Kingdom 472 557 373 Canada 165 4 — Philippines and other 64 40 80 Total income before income tax expense and equity income (loss) by country: $ 2,735 $ 2,602 $ 1,841 As of December 31, 2015 2014 2013 Property, plant and equipment, net by country: United States $ 49,680 $ 47,918 $ 44,460 United Kingdom 5,757 5,563 5,439 Canada 5,298 5,570 3 Philippines and other 34 197 217 Total property, plant and equipment, net by country $ 60,769 $ 59,248 $ 50,119 (1) The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other , relate to other corporate entities, 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, 2015 and 2014 (in millions): BHE MidAmerican NV Northern Pipeline BHE BHE Home- PacifiCorp Funding Energy Powergrid Group Transmission Renewables Services Other Total December 31, 2013 $ 1,129 $ 2,102 $ 2,280 $ 1,149 $ 153 $ — $ 15 $ 695 $ 4 $ 7,527 Acquisitions — — 89 — — 1,700 80 66 — 1,935 Foreign currency translation — — — (49 ) — (43 ) — — (1 ) (93 ) Other — — — — (26 ) — — — — (26 ) 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
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, 2015 2014 2013 Operating revenue: Regulated electric $ 1,837 $ 1,817 $ 1,762 Regulated gas 661 996 824 Nonregulated energy 909 927 817 Total operating revenue $ 3,407 $ 3,740 $ 3,403 Depreciation and amortization: Regulated electric $ 366 $ 312 $ 366 Regulated gas 41 39 37 Total depreciation and amortization $ 407 $ 351 $ 403 Operating income: Regulated electric $ 385 $ 319 $ 255 Regulated gas 64 75 74 Nonregulated energy 22 28 27 Total operating income $ 471 $ 422 $ 356 Interest expense: Regulated electric $ 166 $ 157 $ 136 Regulated gas 17 17 15 Total interest expense $ 183 $ 174 $ 151 Income tax (benefit) expense: Regulated electric $ (163 ) $ (138 ) $ (136 ) Regulated gas 16 22 23 Nonregulated energy 6 12 10 Total income tax (benefit) expense $ (141 ) $ (104 ) $ (103 ) Earnings on common stock: Regulated electric $ 413 $ 361 $ 292 Regulated gas 33 40 41 Nonregulated energy 16 16 16 Total earnings on common stock $ 462 $ 417 $ 349 Years Ended December 31, 2015 2014 2013 Utility construction expenditures: Regulated electric $ 1,365 $ 1,429 $ 945 Regulated gas 81 97 81 Total utility construction expenditures $ 1,446 $ 1,526 $ 1,026 As of December 31, 2015 2014 2013 Total assets: Regulated electric $ 12,970 $ 11,850 $ 10,521 Regulated gas 1,251 1,217 1,196 Nonregulated energy 164 167 131 Total assets $ 14,385 $ 13,234 $ 11,848
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, 2015 2014 2013 Operating revenue: Regulated electric $ 1,837 $ 1,817 $ 1,762 Regulated gas 661 996 824 Nonregulated energy 910 927 817 Other 12 22 10 Total operating revenue $ 3,420 $ 3,762 $ 3,413 Depreciation and amortization: Regulated electric $ 366 $ 312 $ 366 Regulated gas 41 39 37 Total depreciation and amortization $ 407 $ 351 $ 403 Operating income: Regulated electric $ 385 $ 319 $ 255 Regulated gas 64 75 74 Nonregulated energy 22 28 27 Other 2 1 1 Total operating income $ 473 $ 423 $ 357 Interest expense: Regulated electric $ 166 $ 157 $ 136 Regulated gas 17 17 15 Other 23 23 23 Total interest expense $ 206 $ 197 $ 174 Income tax (benefit) expense: Regulated electric $ (163 ) $ (138 ) $ (136 ) Regulated gas 16 22 23 Nonregulated energy 6 12 10 Other (3 ) (6 ) (7 ) Total income tax (benefit) expense $ (144 ) $ (110 ) $ (110 ) Net income attributable to MidAmerican Funding: Regulated electric $ 413 $ 361 $ 292 Regulated gas 33 40 41 Nonregulated energy 16 16 16 Other (4 ) (8 ) (9 ) Total net income attributable to MidAmerican Funding $ 458 $ 409 $ 340 Utility construction expenditures: Regulated electric $ 1,365 $ 1,429 $ 945 Regulated gas 81 97 81 Total utility construction expenditures $ 1,446 $ 1,526 $ 1,026 As of December 31, 2015 2014 2013 Total assets: Regulated electric $ 14,161 $ 13,041 $ 11,712 Regulated gas 1,330 1,296 1,275 Nonregulated energy 164 167 131 Other 19 18 28 Total assets $ 15,674 $ 14,522 $ 13,146
Schedule of Goodwill [Table Text Block]	Goodwill by reportable segment as of December 31, 2015 and 2014 , 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, 2015 2014 2013 Operating revenue: Regulated electric $ 810 $ 779 $ 747 Regulated gas 137 125 106 Total operating revenue $ 947 $ 904 $ 853 Cost of sales: Regulated electric $ 374 $ 361 $ 292 Regulated gas 84 76 56 Total cost of sales $ 458 $ 437 $ 348 Gross margin: Regulated electric $ 436 $ 418 $ 455 Regulated gas 53 49 50 Total gross margin $ 489 $ 467 $ 505 Operating and maintenance: Regulated electric $ 146 $ 140 $ 176 Regulated gas 17 18 21 Total operating and maintenance $ 163 $ 158 $ 197 Depreciation and amortization: Regulated electric $ 96 $ 90 $ 106 Regulated gas 17 15 17 Total depreciation and amortization $ 113 $ 105 $ 123 Operating income: Regulated electric $ 168 $ 165 $ 134 Regulated gas 16 13 6 Total operating income $ 184 $ 178 $ 140 Interest expense: Regulated electric $ 56 $ 57 $ 56 Regulated gas 5 4 5 Total interest expense $ 61 $ 61 $ 61 Income tax expense: Regulated electric $ 43 $ 43 $ 32 Regulated gas 4 4 1 Total income tax expense $ 47 $ 47 $ 33 Years Ended December 31, 2015 2014 2013 Capital expenditures: Regulated electric $ 229 $ 168 $ 125 Regulated gas 23 18 14 Total capital expenditures $ 252 $ 186 $ 139 As of December 31, Total assets: 2015 2014 2013 Regulated electric $ 3,060 $ 2,984 $ 2,905 Regulated gas 316 322 329 Regulated common assets (1) 111 30 77 Total assets $ 3,487 $ 3,336 $ 3,311 (1) Consists principally of cash and cash equivalents not included in either the regulated electric or regulated natural gas segments.

Unaudited Quarterly Operating63

Unaudited Quarterly Operating Results Unaudited Quarterly Operating Results (Tables)	12 Months Ended
	Dec. 31, 2015
MidAmerican Energy Company [Member]
Quarterly Operating Results [Line Items]
Schedule of Quarterly Financial Information [Table Text Block]	2015 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 946 $ 793 $ 920 $ 748 Operating income 106 122 210 33 Net income 94 131 234 3 2014 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 1,225 $ 769 $ 862 $ 884 Operating income 153 51 160 58 Net income 157 32 170 58 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]	2015 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 951 $ 797 $ 921 $ 751 Operating income 107 122 211 33 Net income 99 129 231 (1 ) 2014 1 st Quarter 2 nd Quarter 3 rd Quarter 4 th Quarter (In millions) Operating revenue $ 1,230 $ 775 $ 864 $ 893 Operating income 153 51 161 58 Net income 155 30 168 56 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, 2015 2015 2015 2015 Operating revenues $ 459 $ 607 $ 878 $ 458 Operating income 74 136 329 74 Net income 24 60 187 17 Three-Month Periods Ended March 31, June 30, September 30, December 31, 2014 2014 2014 2014 Operating revenues $ 417 $ 595 $ 867 $ 458 Operating income 55 145 307 34 Net income 6 62 168 (9 )
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, 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 Three-Month Periods Ended March 31, June 30, September 30, December 31, 2014 2014 2014 2014 Regulated electric operating revenue $ 177 $ 179 $ 233 $ 190 Regulated natural gas operating revenue 44 21 18 42 Operating income 46 31 60 41 Net income 22 14 31 20

Organization and Operations (De

Organization and Operations (Details)	12 Months Ended
	Dec. 31, 2015OperatingSegmentsOwnedAndOperatedCompanies
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 Accoun65

Summary of Significant Accounting Policies - Allowance for Doubtful Accounts (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Allowance for Doubtful Accounts [Line Items]
Allowance for doubtful accounts	$ 31	$ 37

Summary of Significant Accoun66

Summary of Significant Accounting Policies - Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Summary of Significant Accounting Policies - Inventory [Abstract]
Energy Related Inventory, Other Fossil Fuel	$ 353	$ 320
Inventory, Raw Materials and Supplies, Gross	529	506
Replacement cost of inventory	$ 8	$ 41

Summary of Significant Accoun67

Summary of Significant Accounting Policies - Goodwill (Details) $ in Millions	12 Months Ended
	Dec. 31, 2013USD ($)
Significant Accounting Policies - Goodwill [Abstract]
Goodwill impairment	$ 53

Summary of Significant Accoun68

Summary of Significant Accounting Policies - Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Significant Accounting Policies - Revenue Recognition [Abstract]
Unbilled revenue	$ 660	$ 666

Summary of Significant Accoun69

Summary of Significant Accounting Policies - Income Taxes (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Significant Accounting Policies - Income Taxes [Abstract]
Regulatory asset, deferred income taxes	$ 1,500	$ 1,400
Regulatory liability, deferred income taxes	29	$ 24
Undistributed earnings of foreign subsidiaries	$ 3,000

Summary of Significant Accoun70

Summary of Significant Accounting Policies New Accounting Pronouncements (Details) - BHE - USD ($) $ in Millions	Jan. 01, 2015	Dec. 31, 2014
Accounting Standards Update 2015-17 [Member] | Other Current Assets [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		$ 291
Accounting Standards Update 2015-17 [Member] | Other Current Liabilities [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		3
Accounting Standards Update 2015-17 [Member] | Deferred Income Taxes [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		288
Accounting Standards Update 2015-03 [Member] | Other Assets [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		197
Accounting Standards Update 2015-03 [Member] | Senior Notes [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		50
Accounting Standards Update 2015-03 [Member] | Long-term Debt [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		$ 147
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 Accoun71

Summary of SIgnificant Accounting Policies - PacifiCorp - Investments (Details) - USD ($)	Dec. 31, 2015	Dec. 31, 2014
PacifiCorp [Member]
Unrealized gains and losses on available-for-sale securities	$ 0	$ 0

Summary of Significant Accoun72

Summary of Significant Accounting Policies - PacifiCorp - Allowance for Doubtful Accounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Valuation and Qualifying Accounts Disclosure [Line Items]
Beginning balance	$ 37
Ending balance	31	$ 37
PacifiCorp [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Beginning balance	7	8
Ending balance	7	7	$ 8
Allowance for Doubtful Accounts [Member] | PacifiCorp [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Beginning balance	7	8	9
Charged to operating costs and expenses, net	10	11	13
Write-offs, net	$ 10	12	14
Ending balance		$ 7	$ 8

Summary of Significant Accoun73

Summary of Significant Accounting Policies - PacifiCorp - Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Unbilled revenue	$ 660	$ 666
PacifiCorp [Member]
Unbilled revenue	$ 245	$ 243

Summary of Significant Accoun74

Summary of Significant Accounting Policies - PacifiCorp - Income Taxes (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Assets and Liabilities [Line Items]
Total regulatory assets		$ 4,285	$ 4,253
Regulatory Liabilities		3,033	2,832
Deferred Income Tax Charge [Member]
Deferred Tax Assets and Liabilities [Line Items]
Total regulatory assets	[1]	1,577	1,468
PacifiCorp [Member]
Deferred Tax Assets and Liabilities [Line Items]
Total regulatory assets		1,685	1,705
Regulatory Liabilities		972	944
Deferred investment tax credit		23	27
PacifiCorp [Member] | Deferred Income Tax Charge [Member]
Deferred Tax Assets and Liabilities [Line Items]
Total regulatory assets	[2]	437	446
PacifiCorp [Member] | Deferred Income Tax Charge [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory Liabilities		$ 12	$ 13
[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 Accoun75

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Pacificorp - New Accounting Pronouncements (Details) $ in Millions	Dec. 31, 2014USD ($)
Other Current Assets [Member] | Accounting Standards Update 2015-17 [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	$ 291
PacifiCorp [Member] | Other Current Assets [Member] | Accounting Standards Update 2015-17 [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	28
PacifiCorp [Member] | Other Noncurrent Liabilities [Member] | Accounting Standards Update 2015-17 [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	28
PacifiCorp [Member] | Other Noncurrent Liabilities [Member] | Accounting Standards Update 2015-03 [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	34
PacifiCorp [Member] | Other Noncurrent Assets [Member] | Accounting Standards Update 2015-03 [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	$ 34

Summary of Significant Accoun76

Summary of Significant Accounting Policies - MEC - Allowance for Doubtful Accounts (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Valuation and Qualifying Accounts Disclosure [Line Items]
Allowance for Doubtful Accounts Receivable, Current	$ 31	$ 37
MidAmerican Energy Company [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Allowance for Doubtful Accounts Receivable, Current	$ 6	$ 7

Summary of Significant Accoun77

Summary of Significant Accounting Policies - MEC - Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	$ 529	$ 506
Replacement cost of inventory	8	41
MidAmerican Energy Company [Member]
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	105	101
Public utility inventory, coal	102	54
Public utility inventory - natural gas in storage	27	24
Replacement cost of inventory	$ 8	$ 41

Summary of Significant Accoun78

Summary of Significant Accounting Policies - MEC - Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Unbilled revenue	$ 660	$ 666
MidAmerican Energy Company [Member]
Unbilled revenue	138	131
Adjustment clause accounts receivable (payable)	$ 17	$ 25

Summary of Significant Accoun79

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - MEC - Income Taxes (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Assets and Liabilities [Line Items]
Regulatory assets		$ 4,155	$ 4,000
MidAmerican Energy Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory assets		1,044	908
Deferred Income Tax Charge [Member] | MidAmerican Energy Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory assets	[1]	$ 858	$ 730
[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 Summary of Significant Accounting Policies - MEC - New Accounting Pronouncements (Details) $ in Millions	Dec. 31, 2014USD ($)
Other Current Assets [Member] | Accounting Standards Update 2015-17 [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	$ 291
Other Current Assets [Member] | MidAmerican Energy Company [Member] | Accounting Standards Update 2015-17 [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	1
Deferred Income Taxes [Member] | Accounting Standards Update 2015-17 [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	288
Deferred Income Taxes [Member] | MidAmerican Energy Company [Member] | Accounting Standards Update 2015-17 [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	1
Other Noncurrent Assets [Member] | MidAmerican Energy Company [Member] | Accounting Standards Update 2015-03 [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	22
Long-term Debt [Member] | Accounting Standards Update 2015-03 [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	147
Long-term Debt [Member] | MidAmerican Energy Company [Member] | Accounting Standards Update 2015-03 [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	$ 22

Summary of Significant Accoun81

Summary of Significant Accounting Policies - MidAmerican Funding - Goodwill (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Goodwill [Line Items]
Goodwill impairment			$ 53
MidAmerican Funding, LLC and Subsidiaries [Domain]
Goodwill [Line Items]
Goodwill impairment	$ 0	$ 0	$ 0

Summary of Significant Accoun82

Summary of Significant Accounting Policies - NPC - Allowance for Doubtful Accounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Allowance for Doubtful Accounts [Line Items]
Beginning balance	$ 37
Ending balance	31	$ 37
Nevada Power Company [Member] | Allowance for Doubtful Accounts [Member]
Allowance for Doubtful Accounts [Line Items]
Beginning balance	14	8	$ 8
Charged to operating costs and expenses, net	16	14	15
Write-offs, net	17	8	15
Ending balance	$ 13	$ 14	$ 8

Summary of Significant Accoun83

Summary of Significant Accounting Policies - NPC - Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	$ 529	$ 506
Energy Related Inventory, Other Fossil Fuel	353	320
Nevada Power Company [Member]
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	58	58
Energy Related Inventory, Other Fossil Fuel	$ 22	$ 30

Summary of Significant Accoun84

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - NPC - Property, Plant and Equipment, Net (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
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 Accoun85

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - NPC - Income Taxes (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Assets and Liabilities [Line Items]
Regulatory asset, deferred income taxes	$ 1,500	$ 1,400
Regulatory liability, deferred income taxes	29	24
Nevada Power Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory asset, deferred income taxes	149	156
Regulatory liability, deferred income taxes	$ 10	$ 3

Summary of Significant Accoun86

Summary of Significant Accounting Policies - NPC - Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Unbilled Receivables, Current	$ 660	$ 666
Nevada Power Company [Member]
Unbilled Receivables, Current	$ 116	$ 111

Summary of Significant Accoun87

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - NPC - New Accounting Pronouncements (Details) $ in Millions	Dec. 31, 2014USD ($)
Other Current Assets [Member] | Accounting Standards Update 2015-17 [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	$ 291
Nevada Power Company [Member] | Other Current Assets [Member] | Accounting Standards Update 2015-17 [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	145
Nevada Power Company [Member] | Other Noncurrent Assets [Member] | Accounting Standards Update 2015-03 [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	32
Nevada Power Company [Member] | Other Noncurrent Liabilities [Member] | Accounting Standards Update 2015-17 [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	145
Nevada Power Company [Member] | Other Noncurrent Liabilities [Member] | Accounting Standards Update 2015-03 [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	$ 32

Summary of Significant Accoun88

Summary of Significant Accounting Policies - SPPC - Allowance for Doubtful Accounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Allowance for Doubtful Accounts [Line Items]
Beginning balance	$ 37
Ending balance	31	$ 37
Sierra Pacific Power Company [Member] | Allowance for Doubtful Accounts [Member]
Allowance for Doubtful Accounts [Line Items]
Beginning balance	2	1	$ 1
Charged to operating costs and expenses, net	1	2	2
Write-offs, net	2	1	2
Ending balance	$ 1	$ 2	$ 1

Summary of Significant Accoun89

Summary of Significant Accounting Policies - SPPC - Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	$ 529	$ 506
Energy Related Inventory, Other Fossil Fuel	353	320
Sierra Pacific Power Company [Member]
Inventory [Line Items]
Inventory, Raw Materials and Supplies, Gross	34	32
Energy Related Inventory, Other Fossil Fuel	$ 5	$ 8

Summary of Significant Accoun90

Summary of Significant Accounting Policies - SPPC - Property, Plant and Equipment, Net (Details) - Sierra Pacific Power Company [Member]	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Electricity Generation Plant, Non-Nuclear [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Allowance for Funds Used During Construction, Rate	7.62%	7.58%
Natural Gas Processing Plant [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Allowance for Funds Used During Construction, Rate	5.97%	4.96%
Common Facilities [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Allowance for Funds Used During Construction, Rate	7.44%	7.28%

Summary of Significant Accoun91

Summary of Significant Accounting Policies - SPPC - Income Taxes (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Assets and Liabilities [Line Items]
Regulatory asset, deferred income taxes	$ 1,500	$ 1,400
Regulatory liability, deferred income taxes	29	24
Sierra Pacific Power Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory asset, deferred income taxes	90	94
Regulatory liability, deferred income taxes	$ 7	$ 8

Summary of Significant Accoun92

Summary of Significant Accounting Policies - SPPC - Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Unbilled revenue	$ 660	$ 666
Sierra Pacific Power Company [Member]
Unbilled revenue	$ 59	$ 57

Summary of Significant Accoun93

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - SPPC - New Accounting Pronouncements (Details) $ in Millions	Dec. 31, 2014USD ($)
Accounting Standards Update 2015-17 [Member] | Other Current Assets [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	$ 291
Sierra Pacific Power Company [Member] | Accounting Standards Update 2015-17 [Member] | Other Current Assets [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	42
Sierra Pacific Power Company [Member] | Accounting Standards Update 2015-17 [Member] | Other Noncurrent Liabilities [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	42
Sierra Pacific Power Company [Member] | Accounting Standards Update 2015-03 [Member] | Other Noncurrent Assets [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	10
Sierra Pacific Power Company [Member] | Accounting Standards Update 2015-03 [Member] | Other Noncurrent Liabilities [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	$ 10

Business Acquisitions (Details)

Business Acquisitions (Details) $ / shares in Units, natural_gas_customers in Millions, electricity_customers in Millions, CAD in Millions, $ in Millions	1 Months Ended		12 Months Ended
	Dec. 31, 2014USD ($)substationnatural_gas_customersmielectricity_customers	Dec. 31, 2013USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)substationnatural_gas_customersmielectricity_customers	Dec. 31, 2014CAD	Dec. 31, 2013USD ($)	Dec. 01, 2014USD ($)	Dec. 01, 2014CAD	Dec. 19, 2013$ / shares	Nov. 08, 2013USD ($)
Business Acquisition [Line Items]
Business Acquisition, Measurement Period				12	12
Acquisition, net of cash acquired			$ (164)	$ (2,956)		$ (5,536)
Goodwill	$ 9,343	$ 7,527	9,076	9,343		7,527
Goodwill, acquired during period			77	$ 1,935
Number of years committed to invest in Alberta's infrastructure				3	3
Par value			38,133
Net income attributable to BHE shareholders			2,370	$ 2,095		1,636
AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Cash and equivalents assumed							$ 15
Current assets, including cash and cash equivalents							174
Property, plant, and equipment assumed							5,610
Goodwill							1,744
Other long-term assets assumed							141
Total assets assumed							7,669
Current liabilities, including current portion of long-term debt assumed							866
Current portion of long-term debt assumed							79
Subsidiary debt, less current portion assumed							3,772
Deferred income taxes assumed							85
Other long-term liabilities assumed							218
Other long-term liabilities assumed							4,941
Net assets acquired							$ 2,728	CAD 3,100
Transmission Line | mi	8,100			8,100
Substation | substation	300			300
Percentage of earnings committed to reinvest				100.00%	100.00%
Number of years committed to reinvest earnings				5	5
Investment commitment in Alberta's infrastructure | CAD					CAD 2,700
Minimum amount pursue joint development opportunities with Canadian partners in Canada and the United States | CAD					27
Minimum investment of new funds to support Alberta-based academic programs focused on energy-related topics cultural organizations and community-based programs | CAD					3
Amount committed to invest in community and charitable contributions across Alberta | CAD					CAD 3
The number of years committed to invest in community and charitable contributions across Alberta				3	3
NV Energy Transaction [Member]
Business Acquisition [Line Items]
Credit to retail customers, Net of Tax						13
Credit to retail customers						20
Costs and expenses of an acquired entity						38
Other acquisitions [Member]
Business Acquisition [Line Items]
Acquisition, net of cash acquired			(164)	$ (243)
Business combination, recognized identifiable assets acquired and liabilities assumed, liabilities			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			33	80
Residential real estate brokerage business [Member]
Business Acquisition [Line Items]
Acquisition, net of cash acquired						(240)
Goodwill, acquired during period						188
Business combination, recognized identifiable assets acquired and liabilities assumed, liabilities		271				271
AltaLink [Member]
Business Acquisition [Line Items]
Net income attributable to BHE shareholders				$ 13
NV Energy [Member]
Business Acquisition [Line Items]
Number of electricity customers | electricity_customers	1.2			1.2
Number of natural gas customers | natural_gas_customers	0.2			0.2
Goodwill	$ 2,369	2,280	2,369	$ 2,369		2,280
Goodwill, acquired during period			$ 0	89
BHE [Member] | AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs				$ 3
BHE [Member] | NV Energy Transaction [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs						5
Common Stock [Member] | AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Business acquisition, percentage of voting interests acquired							100.00%	100.00%
Common Stock [Member] | NV Energy Transaction [Member]
Business Acquisition [Line Items]
Business Acquisition, Share Price | $ / shares									$ 23.75
Business acquisition, percentage of voting interests acquired									100.00%
Common Stock [Member] | NV Energy Transaction [Member]
Business Acquisition [Line Items]
Payments to acquire businesses, gross		1,000
Junior Subordinated Debt [Member] | AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Payments to acquire businesses, gross	1,500
Junior Subordinated Debt [Member] | NV Energy Transaction [Member]
Business Acquisition [Line Items]
Payments to acquire businesses, gross		2,600
Cash [Member] | NV Energy Transaction [Member]
Business Acquisition [Line Items]
Payments to acquire businesses, gross		$ 2,000
Commercial Paper [Member] | AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Payments to acquire businesses, gross	$ 1,000
BHE [Member] | Senior Notes [Member]
Business Acquisition [Line Items]
Par value										$ 2,000
Change in Control Costs [Member] | NV Energy Transaction [Member]
Business Acquisition [Line Items]
Costs and expenses of an acquired entity						22
Donations [Member] | NV Energy Transaction [Member]
Business Acquisition [Line Items]
Costs and expenses of an acquired entity						$ 16

Business Acquisitions - Pro For

Business Acquisitions - Pro Forma (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
AltaLink, LP Transaction [Member]
Business Acquisition [Line Items]
Pro forma operating revenue	$ 17,888	$ 13,130
Pro forma net income attributable to BHE shareholders	$ 2,155	1,667
NV Energy Transaction [Member]
Business Acquisition [Line Items]
NV Energy non-recurring charges		74
Credit to retail customers, Net of Tax		13
Pro forma operating revenue		15,561
Pro forma net income attributable to BHE shareholders		$ 1,867

Property, Plant and Equipment96

Property, Plant and Equipment, Net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 60,769	$ 59,248	$ 50,119
Regulated Operation [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	76,003	71,305
Accumulated depreciation and amortization	(22,682)	(21,447)
Property, plant and equipment in service, net	53,321	49,858
Construction work-in-progress	2,300	4,300
Regulated Operation [Member] | Utility generation, distribution and transmission system [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 69,248	64,645
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	$ 6,755	6,660
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	$ 5,626	5,035
Accumulated depreciation and amortization	(805)	(839)
Property, plant and equipment in service, net	4,821	4,196
Nonregulated Operation [Member] | Independent power plants [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	4,751	4,362
Nonregulated Operation [Member] | Other assets [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	875	673
Common Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment in service, net	58,142	54,054
Construction work-in-progress	2,627	5,194
Property, plant and equipment, net	$ 60,769	59,248
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	$ 19,039	18,755	18,563
PacifiCorp [Member] | Service Life [Member]
Property, Plant and Equipment [Line Items]
Change in Accounting Estimates, Impact on Period of Change		35
MidAmerican Funding [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 11,737	$ 10,535	9,353
MidAmerican Funding [Member] | Service Life [Member]
Property, Plant and Equipment [Line Items]
Change in Accounting Estimates, Impact on Period of Change			50
MidAmerican Funding [Member] | Electricity Generation Plant, Non-Nuclear [Member]
Property, Plant and Equipment [Line Items]
Change in Accounting Estimates, Impact on Period of Change			20
Change in Accounting Estimates, Impact on Future Periods			$ 49

Property, Plant and Equipment97

Property, Plant and Equipment, Net - PacifiCorp (Details) - PacifiCorp [Member] - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross		$ 26,757	$ 25,813
Public utility accumulated depreciation and amortization		(8,360)	(8,026)
Public Utilities Property, Plant And Equipment In Service, Net		18,397	17,787
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		629	932
Public Utilities, Property, Plant and Equipment, Net		$ 19,026	$ 18,719
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service		2.90%	3.00%	2.80%
Public Utilities, Property, Plant and Equipment, Amount of Acquisition Adjustments		$ 155	$ 143
Public Utilities, Property, Plant and Equipment, Amount of Acquisition Adjustments, Related Accumulated Depreciation		$ 112	107
Minimum [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life		10 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		$ 12,164	11,932
Electric Transmission [Member]
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross		5,914	5,392
Electric Distribution [Member]
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross		6,408	6,197
Other Intangible Assets [Member]
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross	[1]	875	879
Other Capitalized Property Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Electric Property Plant And Equipment In Service Gross		$ 1,396	1,413
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
Service Life [Member]
Property, Plant and Equipment [Line Items]
Change in Accounting Estimates, Impact on Period of Change			$ 35
[1]	(1)Computer software costs included in intangible plant are initially assigned a depreciable life of 5 to 10 years.

Property, Plant and Equipment98

Property, Plant and Equipment, Net Property, Plant and Equipment - MEC (Details) - MidAmerican Energy Company [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	$ 11,056	$ 9,913
Public Utilities, Property, Plant and Equipment, Net	$ 11,723	$ 10,519
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	3.00%	2.80%	3.30%
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%	2.80%	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	$ 16,275	$ 14,858
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(5,229)	(4,954)
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	11,046	9,904
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	667	606
Regulated Operation [Member] | Electric Operations [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation or Processing	10,404	9,351
Public Utilities, Property, Plant and Equipment, Transmission	1,305	1,142
Public Utilities, Property, Plant and Equipment, Distribution	3,059	2,933
Regulated Operation [Member] | Natural Gas Processing Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Distribution	1,507	1,432
Nonregulated Operation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(5)	(5)
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	10	9
Gross public utility property, plant and equipment in service	$ 15	$ 14
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	20 years
Public Utilities, Property, Plant and Equipment, Transmission, Useful Life	52 years	52 years
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	20 years	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	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	5 years	5 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	100 years	100 years
Public Utilities, Property, Plant and Equipment, Transmission, Useful Life	70 years	70 years
Public Utilities, Property, Plant and Equipment, Distribution, Useful Life	70 years	70 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	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	45 years	45 years
Electricity Generation Plant, Non-Nuclear [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Change in Accounting Estimates, Impact on Period of Change		$ 20
Change in Accounting Estimates, Impact on Future Periods		$ 49
Service Life [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Change in Accounting Estimates, Impact on Period of Change	$ 50

Property, Plant and Equipment99

Property, Plant and Equipment, Net Property, Plant and Equipment - LLC (Details) - MidAmerican Funding LLC [Member] $ in Millions	Dec. 31, 2014USD ($)
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 22
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	$ 8

Property, Plant and Equipmen100

Property, Plant and Equipment, Net - NPC (Details) - Nevada Power Company [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	$ 6,843	$ 6,883
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	153	120
Public Utilities, Property, Plant and Equipment, Net	$ 6,996	$ 7,003
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	3.00%	3.30%	3.30%
Asset Impairment Charges		$ 29	$ 31
Asset Impairment Charges, 2014 PUCN General Rate Case		19
Regulated Operation [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation or Processing	$ 4,212	4,034
Public Utilities, Property, Plant and Equipment, Distribution	3,118	3,018
Public Utilities, Property, Plant and Equipment, Transmission	1,788	1,757
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment	694	669
Public Utilities, Property, Plant and Equipment, Plant in Service, Excluding Construction Work In Progress	9,812	9,478
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	2,971	2,599
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	6,841	6,879
Nonregulated Operation [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	$ 2	$ 4
Minimum [Member] | Regulated Operation [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life	25 years	25 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	5 years	5 years
Maximum [Member] | Regulated Operation [Member]
Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life	80 years	80 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	65 years	65 years

Property, Plant and Equipmen101

Property, Plant and Equipment, Net - SPPC (Details) - Sierra Pacific Power Company [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Net	$ 2,766	$ 2,640
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	2.90%	3.00%	3.00%
Asset Impairment Charges		$ 12	$ 4
Asset Impairment Charges, 2014 PUCN General Rate Case		8
Electricity Generation Plant, Non-Nuclear [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation or Processing	$ 1,134	1,036
Public Utilities, Property, Plant and Equipment, Distribution	1,382	1,321
Public Utilities, Property, Plant and Equipment, Transmission	739	719
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment	$ 139	$ 123
Electricity Generation Plant, Non-Nuclear [Member] | Minimum [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life	40 years	40 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]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Generation, Useful Life	125 years	125 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]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Distribution	$ 374	$ 366
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment	$ 13	$ 13
Natural Gas Processing Plant [Member] | Minimum [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	8 years	8 years
Natural Gas Processing Plant [Member] | Maximum [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	10 years	10 years
Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Common	$ 265	$ 234
Public Utilities, Property, Plant and Equipment, Plant in Service, Excluding Construction Work In Progress	4,046	3,812
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(1,368)	(1,300)
Public Utilities, Property, Plant and Equipment, Net, Excluding Construction Work In Progress	2,678	2,512
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	88	128
Public Utilities, Property, Plant and Equipment, Net	$ 2,766	$ 2,640
Common Facilities [Member] | Minimum [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]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Property, Plant and Equipment, Common, Useful Life	65 years	65 years

Jointly Owned Utility Facili102

Jointly Owned Utility Facilities (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 9,316
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	3,980
Construction Work in Progress	213
PacifiCorp [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	3,971
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	1,674
Construction Work in Progress	$ 160
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	$ 1,289
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	566
Construction Work in Progress	$ 83
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	$ 469
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	154
Construction Work in Progress	$ 0
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	$ 293
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	94
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	$ 457
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	198
Construction Work in Progress	$ 3
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	$ 239
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	128
Construction Work in Progress	$ 2
PacifiCorp [Member] | Hermiston [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%	[1]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 177	[1]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	71	[1]
Construction Work in Progress	$ 1	[1]
Percentage Of Remaining Output The Entity Has Contracted To Purchase	50.00%
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	213
Construction Work in Progress	$ 18
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	$ 76
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	30
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	$ 30
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	18
Construction Work in Progress	$ 7
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	24
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	$ 577
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	178
Construction Work in Progress	46
MidAmerican Energy Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	4,004
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	1,701
Construction Work in Progress	$ 46
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	$ 245
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	83
Construction Work in Progress	$ 2
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	$ 757
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	405
Construction Work in Progress	$ 7
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%	[2]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 672	[2]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	340	[2]
Construction Work in Progress	$ 27	[2]
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	$ 608
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	297
Construction Work in Progress	$ 6
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%	[3]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 448	[3]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	91	[3]
Construction Work in Progress	0	[3]
Revenue sharing credits netted against facility in service	319
Revenue sharing credits netted against accumulated depreciation	$ 67
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	$ 305
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	148
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	$ 554
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	184
Construction Work in Progress	$ 3
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	$ 415
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	153
Construction Work in Progress	0
NV Energy [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	1,056
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	447
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	$ 224
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	39
Construction Work in Progress	$ 1
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	$ 203
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	141
Construction Work in Progress	$ 1
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	$ 247
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	58
Construction Work in Progress	$ 2
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	$ 382
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	209
Construction Work in Progress	$ 2
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	$ 285
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	158
Construction Work in Progress	$ 1
[1]	PacifiCorp has contracted to purchase the remaining 50% of the output of the Hermiston generating facility.
[2]	Includes amounts related to nuclear fuel.
[3]	Facility in-service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling $319 million and $67 million, respectively.

Jointly Owned Utility Facili103

Jointly Owned Utility Facilities - PacifiCorp (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 9,316
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	3,980
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	213
PacifiCorp [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	3,971
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	1,674
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 160
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	$ 1,289
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	566
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 83
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	$ 469
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	154
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0
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	$ 293
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	94
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	$ 457
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	198
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 3
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	$ 239
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	128
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 2
PacifiCorp [Member] | Hermiston [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%	[1]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 177	[1]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	71	[1]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1	[1]
Percentage Of Remaining Output The Entity Has Contracted To Purchase	50.00%
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	213
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 18
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	$ 76
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	30
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	$ 30
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	18
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 7
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	24
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	$ 577
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	178
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 46
[1]	(1)As discussed in Note 17, PacifiCorp has contracted to purchase the remaining 50% of the output of the Hermiston generating facility.

Jointly Owned Utility Facili104

Jointly Owned Utility Facilities Jointly Owned Utility Facilities - MEC (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 9,316
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	3,980
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	213
MidAmerican Energy Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	4,004
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	1,701
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 46
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	$ 757
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	405
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 7
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	$ 672	[1]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	340	[1]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 27	[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	$ 608
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	297
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 6
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	91	[2]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	0	[2]
Revenue sharing credits netted against facility in service	319
Revenue sharing credits netted against accumulated depreciation	$ 67
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	$ 305
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	148
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	$ 554
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	184
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 3
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	$ 415
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	153
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0
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	$ 245	[3]
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	83	[3]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 2	[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 $67 million, respectively.
[3]	(3)Includes 345 and 161 kilovolt transmission lines and substations.

Jointly Owned Utility Facili105

Jointly Owned Utility Facilities - NPC (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 9,316
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	3,980
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	213
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	235
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 4
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	$ 247
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	58
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 2
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	$ 203
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	141
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1
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	$ 144
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	8
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 1
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	$ 68
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	28
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0

Jointly Owned Utility Facili106

Jointly Owned Utility Facilities - SPPC (Details) $ in Millions	Dec. 31, 2015USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	$ 9,316
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	3,980
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	213
Sierra Pacific Power Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Gross Ownership Amount of Plant in Service	394
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	212
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 2
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	$ 382
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation	209
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 2
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, 2015	Dec. 31, 2014
Regulatory Assets [Line Items]
Regulatory assets		$ 130	$ 253
Regulatory assets, noncurrent		4,155	4,000
Total regulatory assets		4,285	4,253
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		2,300	2,600
Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[1]	$ 1,577	1,468
Regulatory asset amortization period years	[1]	26 years
Employee benefit plans [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[2]	$ 778	747
Regulatory asset amortization period years	[2]	9 years
Asset disposition costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[3]	$ 307	329
Regulatory asset amortization period years	[3]	Various
Deferred net power costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 140	277
Regulatory asset amortization period years		1 year
Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 281	239
Regulatory asset amortization period years		8 years
Unrealized loss on regulated derivative contracts [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 250	223
Regulatory asset amortization period years		5 years
Abandoned Projects [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 136	159
Regulatory asset amortization period years		5 years
Unamortized contract values [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 110	123
Regulatory asset amortization period years		8 years
Regulatory assets other [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 706	$ 688
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]	Includes amounts 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 - Regulat108

Regulatory Matters - Regulatory Liabilities (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Regulatory Liabilities [Line Items]
Regulatory liabilities		$ 402	$ 163
Regulatory liabilities, noncurrent		2,631	2,669
Regulatory Liabilities		3,033	2,832
Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	[1]	$ 2,167	2,215
Weighted average remaining life	[1]	28 years
Asset Retirement Obligation Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 147	169
Weighted average remaining life		22 years
Levelized depreciation [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 199	169
Weighted average remaining life		26 years
Employee benefit plans [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	[2]	$ 13	20
Weighted average remaining life	[2]	12 years
Regulatory liabilities other [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 301	259
Weighted average remaining life		Various
Deferred net power costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 206	$ 0
Weighted average remaining life		2 years
[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.Utah Mine DispositionDue to quality issues with the coal reserves at PacifiCorp's Deer Creek mine in Utah and rising costs at PacifiCorp's wholly owned subsidiary, Energy West Mining Company, PacifiCorp believes the Deer Creek coal reserves are no longer able to be economically mined. As a result, 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 April 2015, PacifiCorp filed all-party settlement stipulations with the UPSC and the WPSC finding that the decision to enter into the Utah Mine Disposition transaction was prudent and in the public interest. The UPSC approved the stipulation in April 2015 and the WPSC approved the stipulation in May 2015. In May 2015, the OPUC issued its final order concluding that the Utah Mine Disposition transaction produces net benefits for customers and was in the public interest. The IPUC also issued an order in May 2015, approving the Utah Mine Disposition and ruling that the decision to enter into the transaction was prudent and in the public interest. Accordingly, in June 2015, PacifiCorp sold the specified Utah mining assets and the replacement and amended coal supply agreements became effective. Refer to Note 12 for discussion of the UMWA 1974 Pension Plan withdrawal and the settlement of the other postretirement benefit obligation for UMWA participants. The Deer Creek mine is currently idled and closure activities have begun.In December 2014, PacifiCorp also filed an advice letter with the California Public Utilities Commission ("CPUC"). 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.

Regulatory Matters - PacifiCorp

Regulatory Matters - PacifiCorp - Regulatory Assets (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Regulatory Assets [Line Items]
Regulatory assets		$ 130	$ 253
Regulatory assets, noncurrent		4,155	4,000
Total regulatory assets		4,285	4,253
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		2,300	2,600
Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[1]	$ 1,577	1,468
Regulatory asset amortization period years	[1]	26 years
Employee benefit plans [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[2]	$ 778	747
Regulatory asset amortization period years	[2]	9 years
Unamortized contract values [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 110	123
Regulatory asset amortization period years		8 years
Deferred net power costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 140	277
Regulatory asset amortization period years		1 year
Unrealized loss on regulated derivative contracts [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 250	223
Regulatory asset amortization period years		5 years
PacifiCorp [Member]
Regulatory Assets [Line Items]
Regulatory assets		$ 102	131
Regulatory assets, noncurrent		1,583	1,574
Total regulatory assets		1,685	1,705
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		1,102	1,505
PacifiCorp [Member] | Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[3]	$ 437	446
Regulatory asset amortization period years	[3]	26 years
PacifiCorp [Member] | Employee benefit plans [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[4]	$ 499	491
Regulatory asset amortization period years	[4]	8 years
PacifiCorp [Member] | Utah mine disposition [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[5]	$ 186	194
Regulatory asset amortization period years	[5]	Various
PacifiCorp [Member] | Unamortized contract values [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 110	123
Regulatory asset amortization period years		8 years
PacifiCorp [Member] | Deferred net power costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 86	122
Regulatory asset amortization period years		1 year
PacifiCorp [Member] | Unrealized loss on regulated derivative contracts [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 133	85
Regulatory asset amortization period years		5 years
PacifiCorp [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 234	$ 244
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 - PacifiC110

Regulatory Matters - PacifiCorp - Regulatory Liabilities (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Regulatory Liabilities [Line Items]
Regulatory liabilities		$ 402	$ 163
Regulatory liabilities, noncurrent		2,631	2,669
Regulatory Liabilities		3,033	2,832
Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	[1]	$ 2,167	2,215
Regulatory liability amortization period years	[1]	28 years
PacifiCorp [Member]
Regulatory Liabilities [Line Items]
Regulatory liabilities		$ 34	34
Regulatory liabilities, noncurrent		938	910
Regulatory Liabilities		972	944
PacifiCorp [Member] | Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liabilities, noncurrent		894	873
Regulatory Liabilities	[2]	$ 894	873
Regulatory liability amortization period years	[2]	26 years
PacifiCorp [Member] | Deferred Income Tax Charge [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 12	13
Regulatory liability amortization period years		Various
PacifiCorp [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 66	$ 58
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, 2015	Dec. 31, 2014
Regulatory Assets [Line Items]
Regulatory assets		$ 4,155	$ 4,000
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		$ 2,300	2,600
Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[1]	26 years
Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		8 years
Employee benefit plans [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[2]	9 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		$ 1,044	908
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		$ 1,000	904
MidAmerican Energy Company [Member] | Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period	[3]	25 years
Regulatory assets	[3]	$ 858	730
MidAmerican Energy Company [Member] | Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period	[4]	6 years
Regulatory assets	[4]	$ 94	62
MidAmerican Energy Company [Member] | Employee benefit plans [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period	[5]	11 years
Regulatory assets	[5]	$ 39	42
MidAmerican Energy Company [Member] | Unrealized loss on regulated derivative contracts [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		1 year
Regulatory assets		$ 20	38
MidAmerican Energy Company [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		Various
Regulatory assets		$ 33	$ 36
[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 11 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 - R112

Regulatory Matters - MEC - Regulatory Liabilities (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Regulatory Liabilities [Line Items]
Regulatory liabilities		$ 2,631	$ 2,669
Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[1]	28 years
Asset Retirement Obligation Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		22 years
MidAmerican Energy Company [Member]
Regulatory Liabilities [Line Items]
Regulatory liabilities		$ 831	837
MidAmerican Energy Company [Member] | Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[2]	25 years
Regulatory liabilities	[2]	$ 653	642
MidAmerican Energy Company [Member] | Asset Retirement Obligation Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[3]	22 years
Regulatory liabilities	[3]	$ 140	159
MidAmerican Energy Company [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		Various
Regulatory liabilities		$ 38	$ 36
[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 utility plant in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
[3]	(2)Amount predominantly represents the excess of nuclear decommission trust assets over the related asset retirement obligation. Refer to Note 11for a discussion of asset retirement obligations.

Regulatory Matters Regulatory M

Regulatory Matters Regulatory Matters - NPC - Regulatory Assets (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Regulatory Assets [Line Items]
Total regulatory assets		$ 4,285	$ 4,253
Regulatory assets		130	253
Regulatory assets		4,155	4,000
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		$ 2,300	2,600
Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[1]	26 years
Total regulatory assets	[1]	$ 1,577	1,468
Employee benefit plans [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[2]	9 years
Total regulatory assets	[2]	$ 778	747
Abandoned Projects [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		5 years
Total regulatory assets		$ 136	159
Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		8 years
Total regulatory assets		$ 281	239
Regulatory assets other [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		Various
Total regulatory assets		$ 706	688
Nevada Power Company [Member]
Regulatory Assets [Line Items]
Total regulatory assets		1,057	1,126
Regulatory assets		0	57
Regulatory assets		1,057	1,069
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		$ 572	788
Nevada Power Company [Member] | Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[3]	P28Y
Total regulatory assets	[3]	$ 149	156
Nevada Power Company [Member] | Acquisition-related Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P28Y
Total regulatory assets		$ 143	149
Nevada Power Company [Member] | Decommissioning costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P7Y
Total regulatory assets		$ 121	113
Nevada Power Company [Member] | Employee benefit plans [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years	[4]	P10Y
Total regulatory assets	[4]	$ 98	85
Nevada Power Company [Member] | Abandoned Projects [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P4Y
Total regulatory assets		$ 91	107
Nevada Power Company [Member] | Deferred Operating Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P20Y
Total regulatory assets		$ 87	61
Nevada Power Company [Member] | Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P7Y
Total regulatory assets		$ 79	80
Nevada Power Company [Member] | Legacy Meters [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P17Y
Total regulatory assets		$ 64	68
Nevada Power Company [Member] | Deferred Excess Energy Costs [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		P2Y
Total regulatory assets		$ 56	129
Nevada Power Company [Member] | Regulatory assets other [Member]
Regulatory Assets [Line Items]
Regulatory asset amortization period years		Various
Total regulatory assets		$ 169	178
Public Utilities Commission, Nevada [Member] | General Rate Case [Member] | Nevada Power Company [Member]
Regulatory Assets [Line Items]
Amount of Impairment to Carrying Amount of Regulatory Assets			$ 5
[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, 2015	Dec. 31, 2014
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 3,033	$ 2,832
Regulatory liabilities		402	163
Regulatory liabilities		$ 2,631	2,669
Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[1]	28 years
Regulatory Liabilities	[1]	$ 2,167	2,215
Regulatory liabilities other [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		Various
Regulatory Liabilities		$ 301	259
Nevada Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		477	366
Regulatory liabilities		173	40
Regulatory liabilities		$ 304	326
Nevada Power Company [Member] | Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years	[2]	P34Y
Regulatory Liabilities	[2]	$ 273	295
Nevada Power Company [Member] | Deferred Excess Energy Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		P2Y
Regulatory Liabilities		$ 139	0
Nevada Power Company [Member] | Energy Efficiency Program [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		P1Y
Regulatory Liabilities		$ 34	25
Nevada Power Company [Member] | Regulatory liabilities other [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		Various
Regulatory Liabilities		$ 31	$ 46
[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] - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Aug. 31, 2015	Dec. 31, 2014	Dec. 31, 2015
Energy Efficiency Rate Case [Member] | Public Utilities Commission, Nevada [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Reduction in revenue requirement	$ 5
Customer Refund Liability, Current		$ 11	$ 18
General Rate Case [Member] | Public Utilities Commission, Nevada [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 38
Public Utilities, Average Price Increase (Decrease), Amount		2.00%
Public Utilities, Property, Plant and Equipment, Amount of Disallowed Costs for Recently Completed Plant		$ 15
Amount of Impairment to Carrying Amount of Regulatory Assets		5
Public Utilities, Gain on Sale		5
2013 FERC Transmission Rate Case [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount		17
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 4
NV Energy Transaction [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Stipulation, Lost Revenue Limit		50.00%

Regulatory Matters - SPPC - Reg

Regulatory Matters - SPPC - Regulatory Assets (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Regulatory Assets [Line Items]
Total regulatory assets		$ 4,285	$ 4,253
Regulatory assets		130	253
Regulatory assets		4,155	4,000
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		2,300	2,600
Employee benefit plans [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[1]	778	747
Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Total regulatory assets	[2]	1,577	1,468
Abandoned Projects [Member]
Regulatory Assets [Line Items]
Total regulatory assets		136	159
Regulatory assets other [Member]
Regulatory Assets [Line Items]
Total regulatory assets		706	688
Sierra Pacific Power Company [Member]
Regulatory Assets [Line Items]
Total regulatory assets		432	476
Regulatory assets		0	32
Regulatory assets		432	444
Remaining Amounts of Regulatory Assets for which No Return on Investment During Recovery Period is Provided		$ 254	269
Sierra Pacific Power Company [Member] | Employee benefit plans [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period	[3]	10 years
Total regulatory assets	[3]	$ 126	115
Sierra Pacific Power Company [Member] | Deferred Income Tax Charge [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period	[4]	28 years
Total regulatory assets	[4]	$ 90	94
Sierra Pacific Power Company [Member] | Acquisition-related Costs [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		31 years
Total regulatory assets		$ 83	87
Sierra Pacific Power Company [Member] | Abandoned Projects [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		9 years
Total regulatory assets		$ 44	51
Sierra Pacific Power Company [Member] | Deferred Excess Energy Costs [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		2 years
Total regulatory assets		$ 0	32
Sierra Pacific Power Company [Member] | Loss on Reacquired Debt [Member]
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		17 years
Total regulatory assets		$ 22	24
Sierra Pacific Power Company [Member] | Regulatory assets other [Member]
Regulatory Assets [Line Items]
Total regulatory assets		$ 67	$ 73
[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 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.
[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.
[4]	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 Matters - SPPC - 117

Regulatory Matters - SPPC - Regulatory Liabilities - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 3,033	$ 2,832
Regulatory liabilities		402	163
Regulatory liabilities		2,631	2,669
Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	[1]	2,167	2,215
Regulatory liabilities other [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		301	259
Sierra Pacific Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		308	301
Regulatory liabilities		78	39
Regulatory liabilities		$ 230	262
Sierra Pacific Power Company [Member] | Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		40 years
Regulatory Liabilities	[2]	$ 208	233
Sierra Pacific Power Company [Member] | Deferred Excess Energy Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		2 years
Regulatory Liabilities		$ 66	0
Sierra Pacific Power Company [Member] | Renewable Energy Program [Member]
Regulatory Liabilities [Line Items]
Regulatory liability amortization period years		1 year
Regulatory Liabilities		$ 8	32
Sierra Pacific Power Company [Member] | Regulatory liabilities other [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities		$ 26	$ 36
[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] - USD ($) $ in Millions	Jul. 01, 2014	Aug. 31, 2015	Dec. 31, 2015	Dec. 31, 2014
Energy Efficiency Rate Case [Member] | Public Utilities Commission, Nevada [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Reduction in revenue requirement		$ 1
Customer Refund Liability, Current			$ 3	$ 2
General Rate Case Companion [Member] | Public Utilities Commission, Nevada [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount			10
Public Utilities, Property, Plant and Equipment, Amount of Disallowed Costs for Recently Completed Plant				7
Amount of Impairment to Carrying Amount of Regulatory Assets				1
2013 FERC Transmission Rate Case [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount				$ 17
Public Utilities, Approved Rate Increase (Decrease), Amount			$ 4
NV Energy Transaction [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Stipulation, Lost Revenue Limit	50.00%			50.00%

Investments and Restricted C119

Investments and Restricted Cash and Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Investments [Abstract]
Investments	$ 1,748	$ 1,393
Equity Method Investments [Abstract]
Equity method investments	1,103	868
Restricted Cash and Investments [Abstract]
Restricted cash and investments	653	657
Investments, including equity method and restricted cash and investments, current	137	115
Investments, including equity method and restricted cash and investments, noncurrent	3,367	2,803
Investments, including equity method and restricted cash and investments	3,504	2,918
Quad Cities Station nuclear decommissioning trust funds [Member]
Restricted Cash and Investments [Abstract]
Decommissioning Fund Investments, Fair Value	429	424
Solar Star and Topaz Projects [Member]
Restricted Cash and Investments [Abstract]
Restricted cash and investments	95	66
Restricted Cash and Investments, Other [Member]
Restricted Cash and Investments [Abstract]
Restricted cash and investments	129	167
Electric Transmission Texas, LLC [Member]
Equity Method Investments [Abstract]
Equity method investments	$ 585	$ 515
Equity method investment, ownership percentage	50.00%	50.00%
Bridger Coal Company [Member]
Equity Method Investments [Abstract]
Equity method investments	$ 190	$ 192
Equity method investment, ownership percentage	66.67%	66.67%
Tax Equity Investments
Equity Method Investments [Abstract]
Equity method investments	$ 168	$ 0
Other equity method investments [Member]
Equity Method Investments [Abstract]
Equity method investments	160	161
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	1,000	649
Investments [Abstract]
Available-for-sale Securities, Equity Securities	1,238	881
Rabbi trusts [Member]
Investments [Abstract]
Life Insurance, Corporate or Bank Owned, Amount	380	386
Other investments [Member]
Investments [Abstract]
Other Investments	$ 130	$ 126

Investments and Restricted C120

Investments and Restricted Cash and Investments Investments and Restricted Cash and Investments - MEC - (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Investments and restricted cash and investments	$ 3,367	$ 2,803
MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Decommissioning Fund Investments, Fair Value	429	424
Life Insurance, Corporate or Bank Owned, Amount	175	175
Available-for-sale Securities, Equity Securities	26	26
Other Investments	4	0
Investments and restricted cash and investments	$ 634	$ 625
Domestic Equity Securities [Member] | MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Nuclear Decommissioning Trust Fund Ownership Percentage	56.00%	56.00%
US Government Corporations and Agencies Securities [Member] | MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Nuclear Decommissioning Trust Fund Ownership Percentage	31.00%	32.00%
Domestic Corporate Debt Securities [Member] | MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Nuclear Decommissioning Trust Fund Ownership Percentage	9.00%	9.00%
Other Securities [Member] | MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Nuclear Decommissioning Trust Fund Ownership Percentage	4.00%	3.00%
Auction Rate Securities [Member] | MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Available-for-sale Debt Securities, Amortized Cost Basis	$ 35	$ 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	$ 3
Minimum [Member] | Auction Rate Securities [Member] | MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Available-for-Sale Securities, Remaining Maturity	2 years
Maximum [Member] | Auction Rate Securities [Member] | MidAmerican Energy Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Available-for-Sale Securities, Remaining Maturity	20 years

Investments and Restricted C121

Investments and Restricted Cash and Investments - MidAmerican Funding - (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
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 F122

Short-Term Debt and Credit Facilities Short-Term Debt and Credit Facilities - Credit Facilities (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,421	$ 6,696
Short-term debt	[1]	974	1,445
Line of Credit Facility, Amounts Supported	[1]	415	625
Line of Credit Facility, Remaining Borrowing Capacity	[1]	5,032	4,626
Berkshire Hathaway Energy [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		2,000	2,000
Short-term debt		253	395
Line of Credit Facility, Amounts Supported		51	28
Line of Credit Facility, Remaining Borrowing Capacity		1,696	1,577
PacifiCorp [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		1,200	1,200
Short-term debt		20	20
Line of Credit Facility, Amounts Supported		160	398
Line of Credit Facility, Remaining Borrowing Capacity		1,020	782
MidAmerican Funding [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		609	609
Short-term debt		0	50
Line of Credit Facility, Amounts Supported		195	195
Line of Credit Facility, Remaining Borrowing Capacity		414	364
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		0	0
Line of Credit Facility, Remaining Borrowing Capacity		650	650
Northern Powergrid Holdings [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		221	265
Short-term debt		0	215
Line of Credit Facility, Amounts Supported		0	0
Line of Credit Facility, Remaining Borrowing Capacity		221	50
AltaLink [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		813	1,119
Short-term debt		401	251
Line of Credit Facility, Amounts Supported		9	4
Line of Credit Facility, Remaining Borrowing Capacity		403	864
Other [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		928	853
Short-term debt		300	514
Line of Credit Facility, Amounts Supported		0	0
Line of Credit Facility, Remaining Borrowing Capacity		$ 628	$ 339
[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 Faciliites (Details) £ in Millions, CAD in Millions, $ in Millions		Dec. 31, 2015USD ($)	Dec. 31, 2015CAD	Dec. 31, 2015GBP (£)	Dec. 31, 2014USD ($)	Dec. 31, 2014GBP (£)	Feb. 29, 2012USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,421			$ 6,696
Line of Credit Facility, Amounts Supported	[1]	(415)			(625)
Short-term Debt	[1]	(974)			(1,445)
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		142			125
Line of Credit Facility, Amounts Supported		(51)			(28)
Short-term Debt		$ (253)			$ (395)
Berkshire Hathaway Energy [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.66%	0.66%	0.66%	0.49%	0.49%
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		$ (51)			$ (28)
PacifiCorp [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		1,200			1,200
Letters of Credit Outstanding, Amount		310			451
Line of Credit Facility, Amounts Supported		(160)			(398)
Short-term Debt		$ (20)			$ (20)
PacifiCorp [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.65%	0.65%	0.65%	0.43%	0.43%
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)			$ (270)
MidAmerican Funding [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		609			609
Line of Credit Facility, Amounts Supported		(195)			(195)
Short-term Debt		$ 0			(50)
MidAmerican Funding [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.35%	0.35%	0.35%
Debt to capitalization ratio		0.65	0.65	0.65
Northern Powergrid Holdings [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 221			265
Line of Credit Facility, Amounts Supported		0			0
Short-term Debt		0			(215)
AltaLink, L.P. [Member]
Line of Credit Facility [Line Items]
Short-term Debt		$ (324)			$ (104)
AltaLink, L.P. [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.85%	0.85%	0.85%	1.26%	1.26%
Debt to capitalization ratio		0.75	0.75	0.75
ALP Investments [Member]
Line of Credit Facility [Line Items]
Short-term Debt		$ (77)			$ (147)
ALP Investments [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.89%	0.89%	0.89%	1.30%	1.30%
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					$ (243)
BHE Renewables [Member]
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount		$ 65			$ 63
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, $1.4 billion, expiring June 2017 [Member] | Berkshire Hathaway Energy [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 1,400
Unsecured credit facility, $600 million, expiring June 2017 [Member] | Berkshire Hathaway Energy [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 June 2017 [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] | 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
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, Weighted Average Interest Rate					1.75%	1.75%
Short-term Debt					$ (184)
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
Uncommitted bank facilities [Member] | Northern Powergrid Holdings [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity					$ 31	£ 42
Debt, Weighted Average Interest Rate					2.00%	2.00%
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					1.41%	1.41%
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		$ 578
Debt, Weighted Average Interest Rate		2.42%	2.42%	2.42%
Short-term Debt		$ (300)
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					$ 503
Debt, Weighted Average Interest Rate					2.25%	2.25%
Short-term Debt					$ (271)
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							$ 646
Letters of Credit Outstanding, Amount		$ 600			$ 245
[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 - PacifiCorp - Credit Facility (Details) $ in Millions		Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,421	$ 6,696
Short-term Debt	[1]	(974)	(1,445)
Line of Credit Facility, Amounts Supported	[1]	(415)	(625)
Line of Credit Facility, Remaining Borrowing Capacity	[1]	5,032	4,626
PacifiCorp [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		1,200	1,200
Short-term Debt		(20)	(20)
Line of Credit Facility, Amounts Supported		(160)	(398)
Line of Credit Facility, Remaining Borrowing Capacity		1,020	782
Letters of Credit Outstanding, Amount		$ 310	$ 451
PacifiCorp [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.65%	0.43%
Debt to capitalization ratio		0.65
PacifiCorp [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.65%	0.43%
PacifiCorp [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Amounts Supported		$ (10)	$ (270)
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		600
PacifiCorp [Member] | Certain transactions required by third parties [Member]
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount		15
PacifiCorp [Member] | Tax exempt bond obligations and commodity contract collateral requirement [Member]
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount		$ 310	$ 451
[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 F125

Short-Term Debt and Credit Facilities - MEC - Credit Facility (Details) $ in Millions		Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,421	$ 6,696
Short-term Debt	[1]	(974)	(1,445)
Line of Credit Facility, Amounts Supported	[1]	(415)	(625)
Line of Credit Facility, Remaining Borrowing Capacity	[1]	5,032	4,626
MidAmerican Energy Company [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		605	605
Short-term Debt		0	(50)
Line of Credit Facility, Amounts Supported		(195)	(195)
Line of Credit Facility, Remaining Borrowing Capacity		$ 410	$ 360
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		0.35%
Regulatory Approval for Additional Short-Term Debt Issuances		$ 605
Unsecured credit facility, $600 million, expiring March 2018 [Member] | MidAmerican Energy Company [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		600
Unsecured 364-day Credit Facility, $5 million, expiring June [Member] | MidAmerican Energy Company [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 F126

Short-Term Debt and Credit Facilities - MidAmerican Funding (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,421	$ 6,696
Unsecured 364-day credit facility, $4 million, expiring June [Member] | MHC, Inc. [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain] | 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, 2016
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 F127

Short-Term Debt and Credit Facilities - NPC - Credit Facility (Details)		Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,421,000,000	$ 6,696,000,000
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	$ 6,000,000
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 F128

Short-Term Debt and Credit Facilities - SPPC - Credit Facility (Details)		Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,421,000,000	$ 6,696,000,000
Sierra Pacific Power Company [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		250,000,000
Long-term Line of Credit		0	0
Sierra Pacific Power Company [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Long-term Line of Credit		$ 0	$ 0
Sierra Pacific Power Company [Member] | Senior unsecured credit facility, $250 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.

BHE Debt (Details)

BHE Debt (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Feb. 29, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
BHE Debt [Line Items]
Par value		$ 38,133
Noncurrent senior debt		7,814	$ 7,810
BHE junior subordinated debentures		2,944	3,794
Interest expense to Berkshire Hathaway		104	78	$ 3
Senior Notes [Member] | Berkshire Hathaway Energy [Member]
BHE Debt [Line Items]
Par value		7,875
Total BHE Senior Debt		7,814	7,810
Current senior debt		0	0
Noncurrent senior debt		7,814	7,810
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		$ 399	$ 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		$ 648	$ 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		$ 348	$ 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		$ 348	$ 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	$ 1,688
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	$ 986
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	$ 738
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		$ 2,944
BHE junior subordinated debentures		$ 2,944	$ 3,794
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		$ 1,444
BHE junior subordinated debentures		$ 1,444	$ 2,294
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate		3.00%	3.00%
Junior Subordinated Debt [Member] | Berkshire Hathaway Energy [Member] | BHE Junior Subordinated Debentures, due 2044 [Member]
BHE Debt [Line Items]
Par value		$ 1,500
BHE junior subordinated debentures		$ 1,500	$ 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%	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%	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%	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%	3.75%
Subsequent Event [Member] | Junior Subordinated Debt [Member] | Berkshire Hathaway Energy [Member] | 5.15%, Senior Notes, due 2043 [Member]
BHE Debt [Line Items]
Amount to be redeemed	$ 500

Subsidiary Debt - Summary (Deta

Subsidiary Debt - Summary (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Par value		$ 38,133
Other Long-term Debt, Noncurrent		26,066	$ 25,616
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		27,314
Other Long-term Debt, Current		1,148	1,232
Other Long-term Debt, Noncurrent		26,066	25,616
Other long-term debt		27,214	26,848
Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		7,204
Other long-term debt		7,159	7,055
Eligible Property Subject To Lien Of Mortgages		25,000
Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Par value		4,627
Other long-term debt		4,560	4,323
Eligible Property Subject To Lien Of Mortgages		13,000
Subsidiary Debt [Member] | NV Energy [Member]
Debt Instrument [Line Items]
Par value		4,840
Other long-term debt		4,860	5,118
Subsidiary Debt [Member] | Northern Powergrid Holdings [Member]
Debt Instrument [Line Items]
Par value	[1]	2,735
Other long-term debt		2,772	2,317
Subsidiary Debt [Member] | BHE Pipeline Group [Member]
Debt Instrument [Line Items]
Par value		1,045
Other long-term debt		1,040	1,358
Subsidiary Debt [Member] | BHE Transmission [Member]
Debt Instrument [Line Items]
Par value	[2]	3,469
Other long-term debt		3,467	3,743
Subsidiary Debt [Member] | BHE Renewables [Member]
Debt Instrument [Line Items]
Par value		3,394
Other long-term debt		3,356	2,934
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		$ 310	$ 451
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%
MidAmerican Energy Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		$ 4,302
Other long-term debt		4,271	$ 4,034
AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	2,926
Other long-term debt		2,911	3,173
ALP Investments [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	543
Other long-term debt		556	492
MEC First Mortgage Bonds, 4.25%, Due May 2046 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		450
Other long-term debt		$ 444	$ 0
MEC First Mortgage Bonds, 4.25%, Due May 2046 [Member] | MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MidAmerican Funding [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.25%	0.00%
Series 09-1 Senior Bonds, 5.207%, due 2016 [Member] | ALP Investments [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 108
Other long-term debt		$ 112	$ 136
Debt Instrument, Interest Rate, Stated Percentage		5.207%	5.207%
First Mortgage Bonds, 5.50% To 8.635%, Due Through 2019 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		$ 855
Other long-term debt		$ 853	$ 859
First Mortgage Bonds, 5.50% To 8.635%, Due Through 2019 [Member] | Maximum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.635%	8.635%
First Mortgage Bonds, 5.50% To 8.635%, Due Through 2019 [Member] | Minimum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.50%	5.50%
First Mortgage Bonds, 4.10%, Due 2042 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		$ 300
Other long-term debt		$ 297	$ 297
Debt Instrument, Interest Rate, Stated Percentage		4.10%	4.10%
Capital lease obligations, 8.75% to 15.678%, due through 2035 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		$ 45
Other long-term debt		$ 45	$ 70
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%	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%	8.75%
Series 2015-1 Notes, 4.090%, due 2045 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 253
Other long-term debt		$ 251	$ 0
Debt Instrument, Interest Rate, Stated Percentage		4.09%	0.00%
Series 15-1 Senior Bonds, 2.244%, due 2022 [Member] | ALP Investments [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 145
Other long-term debt		$ 144	$ 0
Debt Instrument, Interest Rate, Stated Percentage		2.244%	0.00%
First Mortgage Bonds, 2.95% To 8.53%, Due 2021 To 2025 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		$ 2,149
Other long-term debt		$ 2,137	$ 1,888
First Mortgage Bonds, 2.95% To 8.53%, Due 2021 To 2025 [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, 2.95% To 8.53%, Due 2021 To 2025 [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, 6.71%, Due 2026 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		$ 100
Other long-term debt		$ 100	$ 100
Debt Instrument, Interest Rate, Stated Percentage		6.71%	6.71%
First Mortgage Bonds, 5.25% To 7.70%, Due 2031 To 2035 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		$ 800
Other long-term debt		$ 794	$ 793
First Mortgage Bonds, 5.25% To 7.70%, Due 2031 To 2035 [Member] | Maximum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.70%	7.70%
First Mortgage Bonds, 5.25% To 7.70%, Due 2031 To 2035 [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, 5.75% To 6.35%, Due 2036 To 2039 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		$ 2,500
Other long-term debt		$ 2,480	$ 2,479
First Mortgage Bonds, 5.75% To 6.35%, Due 2036 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 2036 To 2039 [Member] | Minimum [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.75%	5.75%
Tax-exempt bond obligations, variable rate series, due 2018 to 2025 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value	[3]	$ 107
Other long-term debt	[3]	107	$ 223
Tax-exempt bond obligations, variable rate series, due 2016 to 2024 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value	[3],[4]	198
Other long-term debt	[3],[4]	196	219
Tax-exempt bond obligations, variable rate series, due 2016 to 2025 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value	[4]	59
Other long-term debt	[4]	59	36
Tax-exempt bond obligations, variable rate series, due 2017 to 2018 [Member] | Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		91
Other long-term debt		91	91
Series 12-1 Senior Bonds, 3.674%, due 2019 [Member] | ALP Investments [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	145
Other long-term debt		$ 151	$ 180
Debt Instrument, Interest Rate, Stated Percentage		3.674%	3.674%
Series 13-1 Senior Bonds, 3.265%, due 2020 [Member] | ALP Investments [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 145
Other long-term debt		$ 149	$ 176
Debt Instrument, Interest Rate, Stated Percentage		3.265%	3.265%
Senior debentures, 10.5%, due 2015 [Member] | AltaLink Holdings, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 0
Other long-term debt		$ 0	$ 78
Debt Instrument, Interest Rate, Stated Percentage		0.00%	10.50%
Series 2008-1 Notes, 5.243%, due 2018 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 145
Other long-term debt		$ 145	$ 171
Debt Instrument, Interest Rate, Stated Percentage		5.243%	5.243%
Series 2013-2 Notes, 3.621%, due 2020 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 90
Other long-term debt		$ 90	$ 108
Debt Instrument, Interest Rate, Stated Percentage		3.621%	3.621%
Series 2012-2 Notes, 2.978%, due 2022 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 199
Other long-term debt		$ 198	$ 236
Debt Instrument, Interest Rate, Stated Percentage		2.978%	2.978%
Series 2013-4 Notes, 3.668%, due 2023 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 361
Other long-term debt		$ 360	$ 429
Debt Instrument, Interest Rate, Stated Percentage		3.668%	3.668%
Series 2014-1 Notes, 3.399%, due 2024 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 253
Other long-term debt		$ 252	$ 300
Debt Instrument, Interest Rate, Stated Percentage		3.399%	3.399%
Series 2006-1 Notes, 5.249%, due 2036 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 108
Other long-term debt		$ 108	$ 128
Debt Instrument, Interest Rate, Stated Percentage		5.249%	5.249%
Series 2010-1 Notes, 5.381%, due 2040 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 90
Other long-term debt		$ 90	$ 108
Debt Instrument, Interest Rate, Stated Percentage		5.381%	5.381%
Series 2010-2 Notes, 4.872%, due 2040 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 108
Other long-term debt		$ 108	$ 128
Debt Instrument, Interest Rate, Stated Percentage		4.872%	4.872%
Series 2011-1 Notes, 4.462%, due 2041 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 199
Other long-term debt		$ 198	$ 236
Debt Instrument, Interest Rate, Stated Percentage		4.462%	4.462%
Series 2012-1 Notes, 3.99%, due 2042 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 379
Other long-term debt		$ 374	$ 451
Debt Instrument, Interest Rate, Stated Percentage		3.99%	3.99%
Series 2013-3 Notes, 4.922%, due 2043 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 253
Other long-term debt		$ 252	$ 300
Debt Instrument, Interest Rate, Stated Percentage		4.922%	4.922%
Series 2014-3 Notes, 4.054%, due 2044 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 213
Other long-term debt		$ 212	$ 253
Debt Instrument, Interest Rate, Stated Percentage		4.054%	4.054%
Series 2013-1 Notes, 4.446%, due 2053 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 181
Other long-term debt		$ 180	$ 214
Debt Instrument, Interest Rate, Stated Percentage		4.446%	4.446%
Series 2014-2 Notes, 4.274%, due 2064 [Member] | AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 94
Other long-term debt		$ 93	$ 111
Debt Instrument, Interest Rate, Stated Percentage		4.274%	4.274%
[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.
[3]	Supported by $310 million and $451 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2015 and 2014, 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 - NV Energy (De

Subsidiary Debt - NV Energy (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Par value	$ 38,133
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	27,314
Other long-term debt	27,214	$ 26,848
NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	4,840
Other long-term debt	4,860	5,118
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	$ 373	$ 384
Debt Instrument, Interest Rate, Stated Percentage	6.25%	6.25%
Nevada Power Company [Member]
Debt Instrument [Line Items]
Par value	$ 3,322
Eligible Property Subject To Lien Of Mortgages	$ 8,700
Nevada Power Company [Member] | Mortgage Securities, 5.875%, Series L due 2015 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.875%	5.875%
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, 5.875%, Series L due 2015 [Member]
Debt Instrument [Line Items]
Par value	$ 0
Nevada Power Company [Member] | NV Energy [Member] | Mortgage Securities, 5.950%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Par value	210
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	497
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	3,322
Other long-term debt	3,285	$ 3,544
Nevada Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member] | Mortgage Securities, 5.875%, Series L due 2015 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 0	$ 250
Debt Instrument, Interest Rate, Stated Percentage	0.00%	5.875%
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	$ 210	$ 209
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	$ 323	$ 322
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	$ 497
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	$ 356	$ 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	$ 235	$ 234
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	$ 497	$ 510
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	0.672%	0.454%
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	0.672%	0.454%
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	0.672%	0.455%
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	0.672%	0.455%
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	1.055%	0.459%
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	1.055%	0.459%
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	1.055%	0.464%
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	1.055%	0.464%
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	$ 1,203
Eligible Property Subject To Lien Of Mortgages	$ 3,700
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, 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	$ 450
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, 6.750%, Series P due 2037 [Member]
Debt Instrument [Line Items]
Par value	252
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	58
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	75
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	81
Sierra Pacific Power Company [Member] | NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	1,203
Other long-term debt	1,202	$ 1,190
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	$ 450	$ 451
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	$ 247
Debt Instrument, Interest Rate, Stated Percentage	3.375%	3.375%
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 Revenue Bonds, 0.464% to 0.466%, Series 2006A due 2031 [Member]
Debt Instrument [Line Items]
Other long-term debt	$ 58	$ 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	74	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	$ 80	$ 79
Sierra Pacific Power Company [Member] | Minimum [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	0.733%	0.464%
Sierra Pacific Power Company [Member] | Minimum [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	0.733%	0.464%
Sierra Pacific Power Company [Member] | Minimum [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	0.733%	0.464%
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	0.733%	0.464%
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	0.733%	0.464%
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	0.733%	0.464%
Sierra Pacific Power Company [Member] | Maximum [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	1.054%	0.466%
Sierra Pacific Power Company [Member] | Maximum [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	1.054%	0.466%
Sierra Pacific Power Company [Member] | Maximum [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	1.054%	0.466%
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	1.054%	0.466%
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	1.054%	0.466%
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	1.054%	0.466%

Subsidiary Debt - Northern Powe

Subsidiary Debt - Northern Powergrid (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Par value		$ 38,133
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		27,314
Other long-term debt		27,214	$ 26,848
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[1]	2,735
Other long-term debt		2,772	2,317
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 8.875%, due 2020 [Member]
Debt Instrument [Line Items]
Par value	[1]	147
Other long-term debt		$ 162	$ 172
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]	$ 295
Other long-term debt		$ 315	$ 338
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]	$ 398
Other long-term debt		$ 398	$ 420
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]	$ 295
Other long-term debt		$ 306	$ 324
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]	$ 221
Other long-term debt		$ 217	$ 0
Debt Instrument, Interest Rate, Stated Percentage		2.50%	0.00%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | European Investment Bank loans, 2.564%, due 2017 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 369
Other long-term debt		$ 368	$ 0
Debt Instrument, Interest Rate, Stated Percentage		2.564%	0.00%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 7.25%, due 2028 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 273
Other long-term debt		$ 280	$ 297
Debt Instrument, Interest Rate, Stated Percentage		7.25%	7.25%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 4.375%, due 2032 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 221
Other long-term debt		$ 217	$ 229
Debt Instrument, Interest Rate, Stated Percentage		4.375%	4.375%
Northern Powergrid Holdings [Member] | Subsidiary Debt [Member] | Bonds, 5.125%, due 2035 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 295
Other long-term debt		$ 291	$ 307
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]	$ 221
Other long-term debt		$ 218	$ 230
Debt Instrument, Interest Rate, Stated Percentage		5.125%	5.125%
[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, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Par value	$ 38,133
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	27,314
Other long-term debt	27,214	$ 26,848
BHE Pipeline Group [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	1,045
Other long-term debt	1,040	1,358
Northern Natural Gas [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	800
Other long-term debt	795	894
Northern Natural Gas [Member] | Subsidiary Debt [Member] | Senior Notes, 5.125%, due 2015 [Member]
Debt Instrument [Line Items]
Par value	0
Other long-term debt	0	100
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	247
Kern River [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	245
Other long-term debt	245	464
Kern River [Member] | Subsidiary Debt [Member] | Senior Notes, 6.676%, due 2016 [Member]
Debt Instrument [Line Items]
Par value	0
Other long-term debt	0	165
Kern River [Member] | Subsidiary Debt [Member] | Senior Notes, 4.893%, due 2018 [Member]
Debt Instrument [Line Items]
Par value	245
Other long-term debt	$ 245	$ 299
Northern Natural Gas [Member] | BHE Pipeline Group [Member] | Subsidiary Debt [Member] | Senior Notes, 5.125%, due 2015 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.00%	5.125%
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, 6.676%, due 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.00%	6.676%
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	$ 33	$ 55

Subsidiary Debt Subsidiary Debt

Subsidiary Debt Subsidiary Debt - AltaLink (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Par value		$ 38,133
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		27,314
Other long-term debt		27,214	$ 26,848
ALP Investments [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[1]	543
Other long-term debt		556	492
ALP Investments [Member] | Subsidiary Debt [Member] | Series 09-1 Senior Bonds, 5.207%, due 2016 [Member]
Debt Instrument [Line Items]
Par value	[1]	108
Other long-term debt		$ 112	$ 136
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]	$ 145
Other long-term debt		$ 151	$ 180
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]	$ 145
Other long-term debt		$ 149	$ 176
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]	$ 145
Other long-term debt		$ 144	$ 0
Debt Instrument, Interest Rate, Stated Percentage		2.244%	0.00%
AltaLink Holdings, L.P. [Member] | Subsidiary Debt [Member] | Senior debentures, 10.5%, due 2015 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 0
Other long-term debt		$ 0	$ 78
Debt Instrument, Interest Rate, Stated Percentage		0.00%	10.50%
AltaLink, L.P. [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 2,926
Other long-term debt		2,911	$ 3,173
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2008-1 Notes, 5.243%, due 2018 [Member]
Debt Instrument [Line Items]
Par value	[1]	145
Other long-term debt		$ 145	$ 171
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]	$ 90
Other long-term debt		$ 90	$ 108
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]	$ 199
Other long-term debt		$ 198	$ 236
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]	$ 361
Other long-term debt		$ 360	$ 429
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]	$ 253
Other long-term debt		$ 252	$ 300
Debt Instrument, Interest Rate, Stated Percentage		3.399%	3.399%
AltaLink, L.P. [Member] | Subsidiary Debt [Member] | Series 2006-1 Notes, 5.249%, due 2036 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 108
Other long-term debt		$ 108	$ 128
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]	$ 90
Other long-term debt		$ 90	$ 108
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]	$ 108
Other long-term debt		$ 108	$ 128
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]	$ 199
Other long-term debt		$ 198	$ 236
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]	$ 379
Other long-term debt		$ 374	$ 451
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]	$ 253
Other long-term debt		$ 252	$ 300
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]	$ 213
Other long-term debt		$ 212	$ 253
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]	$ 253
Other long-term debt		$ 251	$ 0
Debt Instrument, Interest Rate, Stated Percentage		4.09%	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]	$ 181
Other long-term debt		$ 180	$ 214
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]	$ 94
Other long-term debt		$ 93	$ 111
Debt Instrument, Interest Rate, Stated Percentage		4.274%	4.274%
BHE Transmission [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 3,469
Other long-term debt		$ 3,467	$ 3,743
[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, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Par value		$ 38,133
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		27,314
Other long-term debt		27,214	$ 26,848
BHE Renewables [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		3,394
Other long-term debt		3,356	2,934
BHE Renewables [Member] | Subsidiary Debt [Member] | CE Generation Bonds 7.416% due 2018 [Member]
Debt Instrument [Line Items]
Par value	[1]	96
Other long-term debt	[1]	$ 97	$ 125
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]	$ 50
Other long-term debt	[1]	$ 51	$ 71
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]	$ 112
Other long-term debt	[1]	$ 113	$ 125
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]	$ 104
Other long-term debt	[1]	$ 102	$ 107
Debt Instrument, Interest Rate, Stated Percentage		5.125%	5.125%
BHE Renewables [Member] | Subsidiary Debt [Member] | Solar Star Funding LLC Series B Senior Secured Notes 3.95% due June 2016 through June 2035 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.95%	0.00%
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]	$ 325
Other long-term debt	[1]	321	$ 0
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]	1,000
Other long-term debt	[1]	$ 988	$ 987
Debt Instrument, Interest Rate, Stated Percentage		5.375%	5.375%
BHE Renewables [Member] | Subsidiary Debt [Member] | Topaz Solar Farms Senior Notes, 5.75%, due 2039 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 826
Other long-term debt	[1]	$ 815	$ 838
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]	$ 242
Other long-term debt	[1]	$ 239	$ 247
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]	$ 25
Other long-term debt	[1]	25	$ 27
BHE Renewables [Member] | Subsidiary Debt [Member] | Pinyon Pines I and II Term Loans, due 2019 [Member]
Debt Instrument [Line Items]
Par value	[1],[2]	380
Other long-term debt	[1],[2]	$ 378	$ 398
Variable interest rate		2.23%	1.88%
Derivative, interest rate swap, portion of debt fixed		75.00%
Interest rate swaps average fixed rate			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]	$ 8
Other long-term debt	[1]	$ 8	$ 9
Debt Instrument, Interest Rate, Stated Percentage		0.09%	0.00%
BHE Renewables [Member] | Subsidiary Debt [Member] | TX Jumbo Road Term Loan, 3.626% due 2025 [Member]
Debt Instrument [Line Items]
Par value	[1]	$ 226
Other long-term debt	[1]	$ 219	$ 0
Debt Instrument, Interest Rate, Stated Percentage		3.626%	0.00%
[1]	Amortizes quarterly or semiannually.
[2]	The term loans have variable interest rates based on LIBOR plus a spread that varies during the term of the agreement. The weighted average variable interest rate as of December 31, 2015 and 2014 was 2.23% and 1.88%, respectively. The Company has entered into interest rate swaps that fix the interest rate on 75% of the outstanding debt. The weighted average fixed interest rate for the 75% portion is fixed at 3.55% as of December 31, 2015 and 2014.

Subsidiary Debt - Maturity Sche

Subsidiary Debt - Maturity Schedule (Details) $ in Millions	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 1,148
Long-term Debt, Maturities, Repayments of Principal in Year Two	985
Long-term Debt, Maturities, Repayments of Principal in Year Three	3,520
Long-term Debt, Maturities, Repayments of Principal in Year Four	2,070
Long-term Debt, Maturities, Repayments of Principal in Year Five	1,589
Long-term Debt, Maturities, Repayments of Principal after Year Five	28,821
Par value	38,133
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value	27,314
PacifiCorp [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	81
Long-term Debt, Maturities, Repayments of Principal in Year Two	57
Long-term Debt, Maturities, Repayments of Principal in Year Three	589
Long-term Debt, Maturities, Repayments of Principal in Year Four	353
Long-term Debt, Maturities, Repayments of Principal in Year Five	41
Long-term Debt, Maturities, Repayments of Principal after Year Five	6,083
Par value	7,204
MidAmerican Funding [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	34
Long-term Debt, Maturities, Repayments of Principal in Year Two	254
Long-term Debt, Maturities, Repayments of Principal in Year Three	350
Long-term Debt, Maturities, Repayments of Principal in Year Four	500
Long-term Debt, Maturities, Repayments of Principal in Year Five	1
Long-term Debt, Maturities, Repayments of Principal after Year Five	3,488
Par value	4,627
NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	676
Long-term Debt, Maturities, Repayments of Principal in Year Two	16
Long-term Debt, Maturities, Repayments of Principal in Year Three	840
Long-term Debt, Maturities, Repayments of Principal in Year Four	519
Long-term Debt, Maturities, Repayments of Principal in Year Five	336
Long-term Debt, Maturities, Repayments of Principal after Year Five	2,453
Par value	4,840
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	0
Long-term Debt, Maturities, Repayments of Principal in Year Three	59
Long-term Debt, Maturities, Repayments of Principal in Year Four	59
Long-term Debt, Maturities, Repayments of Principal in Year Five	500
Long-term Debt, Maturities, Repayments of Principal after Year Five	2,117
Par value	2,735	[1]
BHE Pipeline Group [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	54
Long-term Debt, Maturities, Repayments of Principal in Year Two	62
Long-term Debt, Maturities, Repayments of Principal in Year Three	329
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	600
Par value	1,045
BHE Transmission [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	110
Long-term Debt, Maturities, Repayments of Principal in Year Two	0
Long-term Debt, Maturities, Repayments of Principal in Year Three	145
Long-term Debt, Maturities, Repayments of Principal in Year Four	145
Long-term Debt, Maturities, Repayments of Principal in Year Five	235
Long-term Debt, Maturities, Repayments of Principal after Year Five	2,834
Par value	3,469	[2]
BHE Renewables [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	193
Long-term Debt, Maturities, Repayments of Principal in Year Two	196
Long-term Debt, Maturities, Repayments of Principal in Year Three	208
Long-term Debt, Maturities, Repayments of Principal in Year Four	494
Long-term Debt, Maturities, Repayments of Principal in Year Five	126
Long-term Debt, Maturities, Repayments of Principal after Year Five	2,177
Par value	3,394
Berkshire Hathaway Energy [Member] | Senior Notes [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	400
Long-term Debt, Maturities, Repayments of Principal in Year Three	1,000
Long-term Debt, Maturities, Repayments of Principal in Year Four	0
Long-term Debt, Maturities, Repayments of Principal in Year Five	350
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	2,944
Par value	$ 2,944
[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 D137

Subsidiary Debt Subsidiary Debt - Pacificorp (Details) - USD ($) $ in Millions		Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Par value		$ 38,133
Long-term Debt		37,972		$ 38,649
PacifiCorp [Member]
Debt Instrument [Line Items]
Long-term Debt		7,114		6,985
Long-term Debt and Capital Lease Obligations, Principal Amount		7,191
Current portion of long-term debt and capital lease obligations		68		134
Long-term debt and capital lease obligations		7,078		6,885
Total long-term debt and capital lease obligations		7,146		7,019
Letters of Credit Outstanding, Amount		310		451
Maximum amount of additional long-term debt approved by regulators		1,325
Eligible Property Subject To Lien Of Mortgages		25,000
Capital Leases, Balance Sheet, Assets by Major Class, Net		32		34
PacifiCorp [Member] | Letters of credit supporting tax-exempt bond obligations [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		310		451
PacifiCorp [Member] | First Mortgage Bonds, 5.50% To 8.635%, Due Through 2019 [Member]
Debt Instrument [Line Items]
Par value		855
Long-term Debt		$ 853		$ 859
Long-term Debt, Weighted Average Interest Rate		5.61%		5.63%
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		5.50%		5.50%
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		8.635%		8.635%
PacifiCorp [Member] | First Mortgage Bonds, 2.95% To 8.53%, Due 2021 To 2025 [Member]
Debt Instrument [Line Items]
Par value		$ 2,149
Long-term Debt		$ 2,137		$ 1,888
Long-term Debt, Weighted Average Interest Rate		4.01%		4.09%
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		8.53%		8.53%
PacifiCorp [Member] | First Mortgage Bonds, 6.71%, Due 2026 [Member]
Debt Instrument [Line Items]
Par value		$ 100
Long-term Debt		$ 100		$ 100
Long-term Debt, Weighted Average Interest Rate		6.71%		6.71%
Debt Instrument, Interest Rate, Stated Percentage		6.71%		6.71%
PacifiCorp [Member] | First Mortgage Bonds, 5.25% To 7.70%, Due 2031 To 2035 [Member]
Debt Instrument [Line Items]
Par value		$ 800
Long-term Debt		$ 794		$ 793
Long-term Debt, Weighted Average Interest Rate		6.33%		6.33%
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		7.70%		7.70%
PacifiCorp [Member] | First Mortgage Bonds, 5.75% To 6.35%, Due 2036 To 2039 [Member]
Debt Instrument [Line Items]
Par value		$ 2,500
Long-term Debt		$ 2,480		$ 2,479
Long-term Debt, Weighted Average Interest Rate		6.06%		6.06%
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%
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]	$ 107
Long-term Debt	[1]	$ 107		$ 223
Long-term Debt, Weighted Average Interest Rate	[1]	0.01%		0.03%
PacifiCorp [Member] | Tax-exempt bond obligations, variable rate series, due 2016 to 2024 [Member]
Debt Instrument [Line Items]
Par value	[1],[2]	$ 198
Long-term Debt	[1],[2]	$ 196		$ 219
Long-term Debt, Weighted Average Interest Rate	[1],[2]	0.02%		0.02%
PacifiCorp [Member] | Tax-exempt bond obligations, variable rate series, due 2016 to 2025 [Member]
Debt Instrument [Line Items]
Par value	[2]	$ 59
Long-term Debt	[2]	$ 59		$ 36
Long-term Debt, Weighted Average Interest Rate	[2]	0.21%		0.22%
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		0.22%		0.22%
PacifiCorp [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Par value		$ 7,159
Long-term Debt		$ 7,114		$ 6,985
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		11.25%		11.33%
Capital Lease Obligations		$ 32		$ 34
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, 3.35%, Due July 2025 [Member]
Debt Instrument [Line Items]
Par value			$ 250
Debt Instrument, Interest Rate, Stated Percentage			3.35%
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		$ 27,314
Subsidiary Debt [Member] | PacifiCorp [Member]
Debt Instrument [Line Items]
Par value		7,204
Eligible Property Subject To Lien Of Mortgages		25,000
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 5.50% To 8.635%, Due Through 2019 [Member]
Debt Instrument [Line Items]
Par value		$ 855
Subsidiary Debt [Member] | 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		5.50%		5.50%
Subsidiary Debt [Member] | 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		8.635%		8.635%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 2.95% To 8.53%, Due 2021 To 2025 [Member]
Debt Instrument [Line Items]
Par value		$ 2,149
Subsidiary Debt [Member] | 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%
Subsidiary Debt [Member] | 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		8.53%		8.53%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 6.71%, Due 2026 [Member]
Debt Instrument [Line Items]
Par value		$ 100
Debt Instrument, Interest Rate, Stated Percentage		6.71%		6.71%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 5.25% To 7.70%, Due 2031 To 2035 [Member]
Debt Instrument [Line Items]
Par value		$ 800
Subsidiary Debt [Member] | 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%
Subsidiary Debt [Member] | 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		7.70%		7.70%
Subsidiary Debt [Member] | PacifiCorp [Member] | First Mortgage Bonds, 5.75% To 6.35%, Due 2036 To 2039 [Member]
Debt Instrument [Line Items]
Par value		$ 2,500
Subsidiary Debt [Member] | 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%
Subsidiary Debt [Member] | 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] | PacifiCorp [Member] | First Mortgage Bonds, 4.10%, Due 2042 [Member]
Debt Instrument [Line Items]
Par value		$ 300
Debt Instrument, Interest Rate, Stated Percentage		4.10%		4.10%
Subsidiary Debt [Member] | PacifiCorp [Member] | Tax-exempt bond obligations, variable rate series, due 2018 to 2025 [Member]
Debt Instrument [Line Items]
Par value	[3]	$ 107
Subsidiary Debt [Member] | PacifiCorp [Member] | Tax-exempt bond obligations, variable rate series, due 2016 to 2024 [Member]
Debt Instrument [Line Items]
Par value	[3],[4]	198
Subsidiary Debt [Member] | PacifiCorp [Member] | Tax-exempt bond obligations, variable rate series, due 2016 to 2025 [Member]
Debt Instrument [Line Items]
Par value	[4]	59
Subsidiary Debt [Member] | PacifiCorp [Member] | Tax-exempt bond obligations, variable rate series, due 2017 to 2018 [Member]
Debt Instrument [Line Items]
Par value		$ 91
[1]	1)Supported by $310 million and $451 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2015 and 2014, 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 $310 million and $451 million of fully available letters of credit issued under committed bank arrangements as of December 31, 2015 and 2014, 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 D138

Subsidiary Debt Subsidiary Debt - PacifiCorp - Annual Payment on Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 1,148
Long-term Debt, Maturities, Repayments of Principal in Year Two	985
Long-term Debt, Maturities, Repayments of Principal in Year Three	3,520
Long-term Debt, Maturities, Repayments of Principal in Year Four	2,070
Long-term Debt, Maturities, Repayments of Principal in Year Five	1,589
Long-term Debt, Maturities, Repayments of Principal after Year Five	28,821
Par value	38,133
Long-term Debt	37,972	$ 38,649
PacifiCorp [Member]
Debt Instrument [Line Items]
Long-term Debt and Capital Lease Obligations, Repayments of Principal in Next Twelve Months	71
Long-term Debt and Capital Lease Obligations, Maturities, Repayments of Principal in Year Two	62
Long-term Debt and Capital Lease Obligations, Maturities, Repayments of Principal in Year Three	591
Long-term Debt and Capital Lease Obligations, Maturities, Repayments of Principal in Year Four	355
Long-term Debt and Capital Lease Obligations, Maturities, Repayments of Principal in Year Five	42
Long-term Debt and Capital Lease Obligations, Maturities, Repayments of Principal after Year Five	6,094
Total Long-term Debt Maturities and Capital Leases Future Minimum Payments	7,215
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	(45)
Capital Leases, Future Minimum Payments, Interest Included in Payments	(24)
Long-term Debt	7,114	6,985
Total long-term debt and capital lease obligations	7,146	$ 7,019
PacifiCorp [Member] | Long-term 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	52
Long-term Debt, Maturities, Repayments of Principal in Year Three	586
Long-term Debt, Maturities, Repayments of Principal in Year Four	350
Long-term Debt, Maturities, Repayments of Principal in Year Five	38
Long-term Debt, Maturities, Repayments of Principal after Year Five	6,067
Par value	7,159
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	(45)
Capital Leases, Future Minimum Payments, Interest Included in Payments	0
Long-term Debt	7,114
PacifiCorp [Member] | Capital Lease Obligations [Member]
Debt Instrument [Line Items]
Capital Leases, Future Minimum Payments Due, Next Twelve Months	5
Capital Leases, Future Minimum Payments Due in Two Years	10
Capital Leases, Future Minimum Payments Due in Three Years	5
Capital Leases, Future Minimum Payments Due in Four Years	5
Capital Leases, Future Minimum Payments Due in Five Years	4
Capital Leases, Future Minimum Payments Due Thereafter	27
Capital Leases, Future Minimum Payments Due	56
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	0
Capital Leases, Future Minimum Payments, Interest Included in Payments	(24)
Capital Lease Obligations	$ 32

Subsidiary Debt Subsidiary D139

Subsidiary Debt Subsidiary Debt - MEC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Oct. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Par value	$ 38,133
MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Par value	4,302
Other long-term debt	4,271		$ 4,034
Eligible Property Subject To Lien Of Mortgages	13,000
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		$ 498
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	$ 502		$ 296
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	$ 444		$ 0
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	$ 349		$ 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	$ 395		$ 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] | Turbine Purchase Obligation, 1.43%, Due December 2015 [Member]
Debt Instrument [Line Items]
Par value	$ 0
Other long-term debt	0		$ 420
Vendor Financing, Discount Rate Applied			1.43%
MidAmerican Energy Company [Member] | MEC Transmission Upgrade Obligation, 4.449%, Due Through 2035 [Member]
Debt Instrument [Line Items]
Par value	5
Other long-term debt	$ 4		$ 0
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	$ 34
Other long-term debt	33		33
MidAmerican Energy Company [Member] | Variable Rate Tax Exempt Obligation Series Due 2017 [Member]
Debt Instrument [Line Items]
Par value	4
Other long-term debt	4		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 2038 [Member]
Debt Instrument [Line Items]
Par value	45
Other long-term debt	45		45
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		$ 0
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%		0.07%
MidAmerican Energy Company [Member] | MidAmerican Energy Company [Member] | First Mortgage Bonds Issued October 2015 [Member]
Debt Instrument [Line Items]
Par value		$ 650
MidAmerican Energy Company [Member] | MidAmerican Energy Company [Member] | Turbine Purchase Obligation, 1.43%, Due December 2015 [Member]
Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount	$ 426
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	$ 1,600
Common Equity Level To Total Capitalization [Member] | MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Common Equity Level To Total Capitalization	52.00%

Subsidiary Debt Subsidiary D140

Subsidiary Debt Subsidiary Debt - MEC - Maturity Schedule (Details) $ in Millions	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 1,148
Long-term Debt, Maturities, Repayments of Principal in Year Two	985
Long-term Debt, Maturities, Repayments of Principal in Year Three	3,520
Long-term Debt, Maturities, Repayments of Principal in Year Four	2,070
Long-term Debt, Maturities, Repayments of Principal in Year Five	1,589
Long-term Debt, Maturities, Repayments of Principal after Year Five	28,821
MidAmerican Energy Company [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	34
Long-term Debt, Maturities, Repayments of Principal in Year Two	254
Long-term Debt, Maturities, Repayments of Principal in Year Three	351
Long-term Debt, Maturities, Repayments of Principal in Year Four	500
Long-term Debt, Maturities, Repayments of Principal in Year Five	1
Long-term Debt, Maturities, Repayments of Principal after Year Five	$ 3,162

Subsidiary Debt - MidAmerican F

Subsidiary Debt - MidAmerican Funding (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Par value		$ 38,133
Equity Restrictions		12,700
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		27,314
Other long-term debt		27,214	$ 26,848
MidAmerican Funding [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		4,627
Other long-term debt		4,560	4,323
Eligible Property Subject To Lien Of Mortgages		13,000
MidAmerican Funding, LLC and Subsidiaries [Domain]
Debt Instrument [Line Items]
Equity Restrictions		3,100
MidAmerican Funding LLC [Member] | Subsidiary Debt [Member] | Senior Notes, 6.927%, due 2029 [Member]
Debt Instrument [Line Items]
Par value		325
Other long-term debt		$ 289	$ 289
MidAmerican Funding LLC [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | Senior Notes, 6.927%, due 2029 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.927%	6.927%
MidAmerican Energy Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value		$ 4,302
Other long-term debt		4,271	$ 4,034
MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | Tax-exempt bond obligations, variable rate, due 2016-2038 [Member]
Debt Instrument [Line Items]
Par value		195
Other long-term debt		194	194
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	498
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
MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 3.50%, due 2024 [Member]
Debt Instrument [Line Items]
Par value		500
Other long-term debt		502	296
MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 4.80%, due 2043 [Member]
Debt Instrument [Line Items]
Par value		350
Other long-term debt		345	345
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
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		444	0
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
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		349	349
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		395	395
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
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
MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | Turbine Purchase Obligation, 1.43%, Due December 2015 [Member]
Debt Instrument [Line Items]
Par value	[1]	0
Other long-term debt	[1]	0	420
MidAmerican Energy Company [Member] | Subsidiary Debt [Member] | MEC Transmission Upgrade Obligation, 4.449%, Due Through 2035 [Member]
Debt Instrument [Line Items]
Par value		5
Other long-term debt		4	0
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	$ 0
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%	0.07%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC First Mortgage Bonds, 2.40%, Due March 2019 [Member]
Debt Instrument [Line Items]
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]
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]
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 2043 [Member]
Debt Instrument [Line Items]
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]
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]
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]
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]
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]
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]
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]
Debt Instrument, Interest Rate, Stated Percentage		5.80%	5.80%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | Turbine Purchase Obligation, 1.43%, Due December 2015 [Member]
Debt Instrument [Line Items]
Vendor Financing, Discount Rate Applied		0.00%	1.43%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | MEC Transmission Upgrade Obligation, 4.449%, Due Through 2035 [Member]
Debt Instrument [Line Items]
Vendor Financing, Discount Rate Applied		4.45%	0.00%
MidAmerican Energy Company [Member] | MidAmerican Funding [Member] | Subsidiary Debt [Member] | Capital Lease Obligations, 4.16%, Due Through 2020 [Member]
Debt Instrument [Line Items]
Vendor Financing, Discount Rate Applied		4.16%	0.00%
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
[1]	In conjunction with the construction of wind-powered generating facilities in 2012, MidAmerican Energy accrued as property, plant and equipment amounts for turbine purchases it was not contractually obligated to pay until December 2015. The amount ultimately payable was discounted and recognized upon delivery of the equipment as long-term debt. The discount was amortized as interest expense over the period until payment was due using the effective interest method.

Subsidiary Debt Subsidiary D142

Subsidiary Debt Subsidiary Debt - NPC - Capital and Financial Lease Obligations (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2014	Dec. 31, 2013	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Par value			$ 38,133
Nevada Power Company [Member]
Debt Instrument [Line Items]
Par value			3,322
Total Long-term Debt and Capital and Financial Lease Obligations			3,285	$ 3,544
Long-term Debt and Capital and Financial Lease Obligations, Current			225	264
Long-term Debt and Capital and Financial Lease Obligations			3,060	3,280
Debt Required To Be Tendered		$ 3,000
Debt Instrument, Redemption Price, Percentage		101.00%
Extinguishment of Debt, Amount	$ 5
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value			27,314
Other long-term debt			27,214	26,848
NV Energy [Member] | Nevada Power Company [Member] | Mortgage Securities, 5.875%, Series L due 2015 [Member]
Debt Instrument [Line Items]
Par value			0
NV Energy [Member] | Nevada Power Company [Member] | Mortgage Securities, 5.950%, Series M due 2016 [Member]
Debt Instrument [Line Items]
Par value			210
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			497
NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value			4,840
Other long-term debt			4,860	5,118
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member]
Debt Instrument [Line Items]
Par value			3,322
Other long-term debt			3,285	3,544
NV Energy [Member] | Subsidiary Debt [Member] | Nevada Power Company [Member] | Mortgage Securities, 5.875%, Series L due 2015 [Member]
Debt Instrument [Line Items]
Other long-term debt			0	250
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			210	209
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			323	322
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	497
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
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			356	356
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
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
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			235	234
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			$ 497	$ 510

Subsidiary Debt Subsidiary D143

Subsidiary Debt Subsidiary Debt - NPC - Annual Payment on Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 1,148
Long-term Debt, Maturities, Repayments of Principal in Year Two	985
Long-term Debt, Maturities, Repayments of Principal in Year Three	3,520
Long-term Debt, Maturities, Repayments of Principal in Year Four	2,070
Long-term Debt, Maturities, Repayments of Principal in Year Five	1,589
Long-term Debt, Maturities, Repayments of Principal after Year Five	28,821
Par value	38,133
Long-term Debt	37,972	$ 38,649
Nevada Power Company [Member]
Debt Instrument [Line Items]
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Next Twelve Months	283
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Two	75
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Three	897
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Four	575
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal in Year Five	74
Long-term Debt and Capital and Financial Lease Obligations, Repayments of Principal Thereafter	2,200
Par value	3,322
Total Long-term Debt Maturities and Capital and Financial Leases Future Minimum Payments	4,104
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	37
Executory costs	129
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	653
Long-term Debt	2,788	$ 3,034
Long-term Debt and Capital and Financial Lease Obligations, Including Current Maturities	3,285
Nevada Power Company [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	210
Long-term Debt, Maturities, Repayments of Principal in Year Two	0
Long-term Debt, Maturities, Repayments of Principal in Year Three	823
Long-term Debt, Maturities, Repayments of Principal in Year Four	500
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	2,825
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	37
Executory costs	0
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	0
Long-term Debt	2,788
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	73
Capital and Financial Leases, Future Minimum Payments Due in Two Years	75
Capital and Financial Leases, Future Minimum Payments Due in Three Years	74
Capital and Financial Leases, Future Minimum Payments Due in Four Years	75
Capital and Financial Leases, Future Minimum Payments Due in Five Years	74
Capital and Financial Leases, Future Minimum Payments Due Thereafter	908
Capital and Financial Leases, Future Minimum Payments Due	1,279
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	0
Executory costs	129
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	653
Capital and Financial Lease Obligations	$ 497

Subsidiary Debt Subsidiary D144

Subsidiary Debt Subsidiary Debt - NPC - (Details) - Nevada Power Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)option	Dec. 31, 2014USD ($)
Debt Instrument [Line Items]
Eligible Property Subject To Lien Of Mortgages	$ 8,700
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	$ 27	$ 28
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	8
Long-Term Energy Purchase Contracts [Member]
Debt Instrument [Line Items]
Number Of Years In Renewal Period	30 years
Capital Leased Assets, Gross	$ 40	44
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	$ 410	$ 418
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 D145

Subsidiary Debt Subsidiary Debt - SPPC - Capital and Financial Lease Obligations (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2014	Dec. 31, 2014	Dec. 31, 2015
Debt Instrument [Line Items]
Par value			$ 38,133
Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value			27,314
Other long-term debt		$ 26,848	27,214
Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value			1,203
Total Long-term Debt and Capital and Financial Lease Obligations		1,190	1,202
Long-term Debt and Capital and Financial Lease Obligations, Current		1	453
Long-term Debt and Capital and Financial Lease Obligations		1,189	749
Long-term Debt and Capital and Financial Lease Obligations, Including Current Maturities		1,190	1,202
Debt Required To Be Tendered		$ 702
Debt Instrument, Redemption Price, Percentage		101.00%
Extinguishment of Debt, Amount	$ 0
NV Energy [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value			4,840
Other long-term debt		$ 5,118	4,860
NV Energy [Member] | Sierra Pacific Power Company [Member] | Subsidiary Debt [Member]
Debt Instrument [Line Items]
Par value			1,203
Other long-term debt		$ 1,190	$ 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			$ 450
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		$ 451	$ 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		$ 247	$ 248
Debt Instrument, Interest Rate, Stated Percentage		3.375%	3.375%
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 Revenue Bonds, Variable-Rate, Series 2006A due 2031 [Member] | NV Energy [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Par value			$ 58
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		$ 58	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			75
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		74	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			81
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		79	80
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			37
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		$ 26	$ 37
Minimum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006A due 2031 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Variable interest rate		0.464%	0.733%
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		0.464%	0.733%
Minimum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006B due 2036 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Variable interest rate		0.464%	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		0.464%	0.733%
Minimum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006C due 2036 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Variable interest rate		0.464%	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		0.464%	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] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Variable interest rate		0.466%	1.054%
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		0.466%	1.054%
Maximum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006B due 2036 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Variable interest rate		0.466%	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		0.466%	1.054%
Maximum [Member] | Pollution Control Revenue Bonds, Variable-Rate, Series 2006C due 2036 [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Variable interest rate		0.466%	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		0.466%	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		8.814%	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		8.548%	8.548%
Equipment [Member] | Sierra Pacific Power Company [Member]
Debt Instrument [Line Items]
Capital Leased Assets, Gross		$ 3	$ 3

Subsidiary Debt Subsidiary D146

Subsidiary Debt Subsidiary Debt - SPPC - Annual Payment on Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 1,148
Long-term Debt, Maturities, Repayments of Principal in Year Two	985
Long-term Debt, Maturities, Repayments of Principal in Year Three	3,520
Long-term Debt, Maturities, Repayments of Principal in Year Four	2,070
Long-term Debt, Maturities, Repayments of Principal in Year Five	1,589
Long-term Debt, Maturities, Repayments of Principal after Year Five	28,821
Par value	38,133
Long-term Debt	37,972	$ 38,649
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	456
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	769
Par value	1,203
Total Long-term Debt Maturities and Capital and Financial Leases Future Minimum Payments	1,240
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	(1)
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	(37)
Long-term Debt	1,165	1,164
Long-term Debt and Capital and Financial Lease Obligations, Including Current Maturities	1,202	$ 1,190
Eligible Property Subject To Lien Of Mortgages	3,700
Sierra Pacific Power Company [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	450
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	716
Par value	1,166
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	1,165
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	6
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	53
Capital and Financial Leases, Future Minimum Payments Due	74
Debt Instrument, Unamortized Premium, Discount and Debt Issuance Cost	0
Capital and Financial Leases, Future Minimum Payments, Interest Included in Payments	(37)
Capital and Financial Lease Obligations	$ 37

Subsidiary Debt Subsidiary D147

Subsidiary Debt Subsidiary Debt - SPPC (Details) - Sierra Pacific Power Company [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
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	$ 22	$ 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	$ 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 148

Risk Management and Hedging Activities - Balance Sheet Location (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		$ (237)	$ (197)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		103	75
Derivative Assets (Liabilities), at Fair Value, Net		(134)	(122)
Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		28	41
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		28	41
Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		75	67
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		75	67
Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(145)	(153)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		40	56
Derivative Assets (Liabilities), at Fair Value, Net		(105)	(97)
Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(195)	(152)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		63	19
Derivative Assets (Liabilities), at Fair Value, Net		(132)	(133)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(188)	(158)
Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		28	40
Not Designated as Hedging Instrument [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		72	66
Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(109)	(127)
Not Designated as Hedging Instrument [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(179)	(137)
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(49)	(39)
Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		0	1
Designated as Hedging Instrument [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		3	1
Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(36)	(26)
Designated as Hedging Instrument [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(16)	(15)
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]	106	135
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(292)	(291)
Derivative, Fair Value, Net		(186)	(156)
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		250	223	$ 182	$ 235
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]	25	47
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(4)	(11)
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]	72	66
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]	7	21
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(113)	(146)
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	1
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(175)	(134)
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		3	8
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(50)	(44)
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		0	1
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		1	5
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(33)	(27)
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		2	2
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(17)	(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		7	4
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(9)	(6)
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		7	4
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		(3)	(2)
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)	(4)
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		3	1
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(5)	(4)
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		3	1
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		(4)	(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		$ (1)	$ 0
[1]	The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31, 2015 and 2014, a net regulatory asset of $250 million and $223 million, respectively, was recorded related to the net derivative liability of $186 million and $156 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 149

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, 2015	Dec. 31, 2014	Dec. 31, 2013
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Beginning balance	$ 223	$ 182	$ 235
NV Energy Transaction	0	0	47
Changes In Fair Value Derivatives Recognized In Regulatory Assets Or Liabilities, Net	128	96	29
Net Gains (Losses) Reclassified To Operating Revenue	1	(32)	8
Net losses reclassified to cost of sales	(102)	(23)	(137)
Ending balance	$ 250	$ 223	$ 182

Risk Management and Hedging 150

Risk Management and Hedging Activities - Designated as Hedging Contracts (Details) - Designated as Hedging Instrument [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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	$ (36)
Commodity Contract [Member]
Accumulated Other Comprehensive (Income) Loss, Net, Derivatives [Roll Forward]
Beginning balance	32	$ 12	$ 32
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	52	(6)	(9)
Net gains reclassified to operating revenue	9	0	0
Net (losses) gains reclassified to cost of sales	(47)	26	(11)
Ending balance	$ 46	$ 32	$ 12

Risk Management and Hedging 151

Risk Management and Hedging Activities - Derivative Contract Volumes (Details) gal in Millions, MWh in Millions, Dth in Millions, $ in Millions	Dec. 31, 2015USD ($)galDthMWh	Dec. 31, 2014USD ($)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	10	6
Commodity Contract [Member] | Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	317	308
Commodity Contract [Member] | Fuel purchases (in gallons) [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | gal	11	2
Interest Rate Contract [Member] | Interest Rate Swap [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Notional Amount	$ (653)	$ (443)
Interest Rate Contract [Member] | Mortgage Sale Commitments, Net [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Notional Amount	$ (312)	$ (264)

Risk Management and Hedging 152

Risk Management and Hedging Activities - Collateral and Contingent Features (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 288	$ 243
Collateral Already Posted, Aggregate Fair Value	75	28
Additional Collateral, Aggregate Fair Value	$ 198	$ 182

Risk Management and Hedging 153

Risk Management and Hedging Activities - PacifiCorp - Balance Sheet Location (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		$ (237)	$ (197)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		103	75
Derivative Assets (Liabilities), at Fair Value, Net		(134)	(122)
Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		28	41
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		28	41
Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(145)	(153)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		40	56
Derivative Assets (Liabilities), at Fair Value, Net		(105)	(97)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(188)	(158)
Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		28	40
Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(109)	(127)
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]	106	135
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(292)	(291)
Derivative, Fair Value, Net		(186)	(156)
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		250	223	$ 182	$ 235
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]	25	47
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(4)	(11)
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]	7	21
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	[1]	(113)	(146)
PacifiCorp [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(136)	(85)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		75	28
Derivative Assets (Liabilities), at Fair Value, Net		(61)	(57)
PacifiCorp [Member] | Commodity Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		9	18
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		9	18
PacifiCorp [Member] | Commodity Contract [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		0	0
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		0	0
PacifiCorp [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(56)	(54)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		18	14
Derivative Assets (Liabilities), at Fair Value, Net		(38)	(40)
PacifiCorp [Member] | Commodity Contract [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(89)	(49)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		57	14
Derivative Assets (Liabilities), at Fair Value, Net		(32)	(35)
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		12	29
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(148)	(114)
Derivative, Fair Value, Net		(136)	(85)
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		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		10	28
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(1)	(10)
Derivative, Fair Value, Net		9	18
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		0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		0	0
Derivative, Fair Value, Net		0	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		2	1
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(58)	(55)
Derivative, Fair Value, Net		(56)	(54)
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		(89)	(49)
Derivative, Fair Value, Net		$ (89)	$ (49)
[1]	The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31, 2015 and 2014, a net regulatory asset of $250 million and $223 million, respectively, was recorded related to the net derivative liability of $186 million and $156 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 154

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, 2015	Dec. 31, 2014	Dec. 31, 2013
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Beginning balance	$ 223	$ 182	$ 235
Changes In Fair Value Derivatives Recognized In Regulatory Assets Or Liabilities, Net	128	96	29
Net Gains (Losses) Reclassified To Operating Revenue	1	(32)	8
Ending balance	250	223	182
PacifiCorp [Member]
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Beginning balance	85	55
Changes In Fair Value Derivatives Recognized In Regulatory Assets Or Liabilities, Net	82	45
Net Gains (Losses) Reclassified To Operating Revenue	40	(4)
Net Gains (Losses) Reclassified To Cost Of Domestic Regulated Electric	(74)	(11)
Ending balance	$ 133	$ 85	$ 55

Risk Management and Hedging 155

Risk Management and Hedging Activities - PacifiCorp - Derivative Contract Volumes (Details) - Commodity Contract [Member] gal in Millions, MWh in Millions, Dth in Millions	Dec. 31, 2015galDthMWh	Dec. 31, 2014galDthMWh
Electricity purchases (sales), net, in megawatt hours [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	10	6
Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	317	308
Fuel purchases (in gallons) [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | gal	11	2
PacifiCorp [Member] | Electricity purchases (sales), net, in megawatt hours [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	1	1
PacifiCorp [Member] | Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	111	113
PacifiCorp [Member] | Fuel purchases (in gallons) [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | gal	11	3

Risk Management and Hedging 156

Risk Management and Hedging Activities - PacifiCorp - Collateral and Contingent Features (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 288	$ 243
Collateral Already Posted, Aggregate Fair Value	75	28
Additional Collateral, Aggregate Fair Value	198	182
PacifiCorp [Member]
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	142	113
Collateral Already Posted, Aggregate Fair Value	75	28
Additional Collateral, Aggregate Fair Value	$ 64	$ 75

Risk Management and Hedging 157

Risk Management and Hedging Activities - MEC - Balance Sheet Location (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		$ (237)	$ (197)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		103	75
Derivative Assets (Liabilities), at Fair Value, Net		(134)	(122)
Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		28	41
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		28	41
Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(145)	(153)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		40	56
Derivative Assets (Liabilities), at Fair Value, Net		(105)	(97)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(188)	(158)
Not Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		28	40
Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(109)	(127)
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(49)	(39)
Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		0	1
Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(36)	(26)
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(186)	(156)
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		250	223	$ 182	$ 235
MidAmerican Energy Company [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(72)	(74)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		28	47
Derivative Assets (Liabilities), at Fair Value, Net		(44)	(27)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		9	14
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		9	14
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		4	3
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		0	0
Derivative Assets (Liabilities), at Fair Value, Net		4	3
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(62)	(73)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		22	42
Derivative Assets (Liabilities), at Fair Value, Net		(40)	(31)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		(23)	(18)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		6	5
Derivative Assets (Liabilities), at Fair Value, Net		(17)	(13)
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]	23	37
Derivative Liability, Fair Value, Gross Liability	[1]	(49)	(73)
Derivative, Fair Value, Net	[1]	(26)	(36)
Net Regulatory Asset (Liability), Unrealized Loss (Gain) On Derivative Contracts		20	38	$ 10	$ 45
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]	12	14
Derivative Liability, Fair Value, Gross Liability	[1]	(3)	0
Derivative, Fair Value, Net	[1]	9	14
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]	4	3
Derivative Liability, Fair Value, Gross Liability	[1]	0	0
Derivative, Fair Value, Net	[1]	4	3
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]	5	19
Derivative Liability, Fair Value, Gross Liability	[1]	(36)	(69)
Derivative, Fair Value, Net	[1]	(31)	(50)
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]	2	1
Derivative Liability, Fair Value, Gross Liability	[1]	(10)	(4)
Derivative, Fair Value, Net	[1]	(8)	(3)
MidAmerican Energy Company [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		3	6
Derivative Liability, Fair Value, Gross Liability		(49)	(44)
Derivative, Fair Value, Net		(46)	(38)
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	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	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		1	4
Derivative Liability, Fair Value, Gross Liability		(32)	(27)
Derivative, Fair Value, Net		(31)	(23)
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		2	2
Derivative Liability, Fair Value, Gross Liability		(17)	(17)
Derivative, Fair Value, Net		$ (15)	$ (15)
[1]	(1)MidAmerican Energy's commodity derivatives not designated as hedging contracts are generally included in regulated rates. Accordingly, as of December 31, 2015 and 2014, a net regulatory asset of $20 million and $38 million, respectively, was recorded related to the net derivative liability of $26 million and $36 million, respectively.

Risk Management and Hedging 158

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, 2015	Dec. 31, 2014	Dec. 31, 2013
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Beginning balance	$ 223	$ 182	$ 235
Changes In Fair Value Derivatives Recognized In Regulatory Assets Or Liabilities, Net	128	96	29
Net Gains (Losses) Reclassified To Operating Revenue	1	(32)	8
Ending balance	250	223	182
MidAmerican Energy Company [Member]
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Beginning balance	38	10	45
Changes In Fair Value Derivatives Recognized In Regulatory Assets Or Liabilities, Net	40	61	5
Net Gains (Losses) Reclassified To Operating Revenue	(42)	(28)	(1)
Net Gains (Losses) Reclassified To Cost Of Domestic Regulated Electric	(1)	(1)	(1)
Net Gains (Losses) Reclassified To Cost Of Natural Gas Purchases	(15)	(4)	(38)
Ending balance	20	38	10
Derivative, Gain (Loss) on Derivative, Net	(4)	15	(2)
Other Revenue Net [Member] | MidAmerican Energy Company [Member]
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Derivative, Gain (Loss) on Derivative, Net	15	6	0
Cost Of Natural Gas [Member] | MidAmerican Energy Company [Member]
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Derivative, Gain (Loss) on Derivative, Net	2	0	0
Cost Of Sales Nonregulated [Member] | MidAmerican Energy Company [Member]
Regulatory Assets (Liabilities), Net, Derivatives [Roll Forward]
Derivative, Gain (Loss) on Derivative, Net	$ (21)	$ 9	$ (2)

Risk Management and Hedging 159

Risk Management and Hedging Activities - MEC - Designated as Hedging Activities (Details) - Designated as Hedging Instrument [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accumulated Other Comprehensive (Income) Loss, Net, Derivatives [Roll Forward]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ (36)
Commodity Contract [Member]
Accumulated Other Comprehensive (Income) Loss, Net, Derivatives [Roll Forward]
Beginning balance	32	$ 12	$ 32
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	52	(6)	(9)
Ending balance	46	32	12
Commodity Contract [Member] | MidAmerican Energy Company [Member]
Accumulated Other Comprehensive (Income) Loss, Net, Derivatives [Roll Forward]
Beginning balance	34	11	32
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	58	(3)	(11)
Cash Flow Hedge Gain (Loss) Reclassified To Cost Of Sales Nonregulated	(47)	26	(10)
Ending balance	45	34	11
Gain (Loss) on Cash Flow Hedge Ineffectiveness, Net	(1)	$ (2)	$ 0
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ 32

Risk Management and Hedging 160

Risk Management and Hedging Activities - MEC - Derivative Contract Volumes (Details) - Commodity Contract [Member] MWh in Millions, Dth in Millions	Dec. 31, 2015DthMWh	Dec. 31, 2014DthMWh
Electricity purchases (sales), net, in megawatt hours [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	10	6
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	15	14
Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	317	308
Natural gas purchases, in decatherms [Member] | MidAmerican Energy Company [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	17	19

Risk Management and Hedging 161

Risk Management and Hedging Activities - MEC - Collateral and Contingent Features (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 288	$ 243
Additional Collateral, Aggregate Fair Value	198	182
Collateral Already Posted, Aggregate Fair Value	75	28
MidAmerican Energy Company [Member]
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	66	52
Additional Collateral, Aggregate Fair Value	55	36
Collateral Already Posted, Aggregate Fair Value	$ 0	$ 0

Risk Management and Hedging 162

Risk Management and Hedging Activities Risk Management and Hedging Activities - NPC - Balance Sheet Location (Details) - Commodity Contract [Member] - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
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]	$ 292	$ 291
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]	113	146
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		46	43
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]	8	9
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]	14	21
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		22	30
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		$ 22	$ 30
[1]	The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31, 2015 and 2014, a net regulatory asset of $250 million and $223 million, respectively, was recorded related to the net derivative liability of $186 million and $156 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, 2015 and 2014, a regulatory asset of $22 million and $30 million, respectively, was recorded related to the derivative liability of $22 million and $30 million, respectively.

Risk Management and Hedging 163

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, 2015DthMWh	Dec. 31, 2014DthMWh
Electricity purchases (sales), net, in megawatt hours [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | MWh	(10)	(6)
Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	(317)	(308)
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)	(3)
Nevada Power Company [Member] | Natural gas purchases, in decatherms [Member]
Notional Amounts of Outstanding Derivative Positions [Line Items]
Derivative, Nonmonetary Notional Amount | Dth	(126)	(115)

Risk Management and Hedging 164

Risk Management and Hedging Activities Risk Management and Hedging Activities - NPC - Collateral and Contingent Features (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 288	$ 243
Nevada Power Company [Member]
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 3

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Millions		Dec. 31, 2015		Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral receivable (payable), offset against derivative positions		$ 103		$ 75
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]	(16)		(40)
Assets, Fair Value Disclosure		2,692		2,193
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	119		115
Derivative Liability		(237)		(230)
Cash collateral receivable (payable), offset against derivative positions		103	[1]	75
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		2,173		1,718
Derivative Liability		(13)		(18)
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		393		376
Derivative Liability		(296)		(284)
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		142		139
Derivative Liability		(47)		(43)
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		327		279
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		327		279
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]	421		320
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]	421		320
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		133		136
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		133		136
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		2		1
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		2		1
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		39		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		39		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		1		2
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		1		2
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		3		2
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		3		2
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		45
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		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		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		45
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		239		238
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		239		238
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		1,244		886
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		1,244		886
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		136		137
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		136		137
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]	(16)		(40)
Derivative assets		93		103
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	119		115
Derivative Liability		(223)		(220)
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		0		1
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		13		18
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		16		48
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		283		274
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		93		94
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		46		43
Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		10		5
Derivative Liability		(14)		(10)
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		0		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		5		5
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		13		10
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		5		0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		$ 1		$ 0
[1]	Represents netting under master netting arrangements and a net cash collateral receivable of $103 million and $75 million as of December 31, 2015 and 2014, 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, 2015	Dec. 31, 2014	Dec. 31, 2013
Commodity [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 51	$ 60	$ 32
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	19	19	34
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)	(7)	0	(2)
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net	(19)	5	1
Purchases	1	1	4
Settlements	2	1	(9)
Transfers from level 2	0	(35)	0
Ending balance	47	51	60
Interest Rate Lock Commitments [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	0	0	0
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	87	0	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
Settlements	(86)	0	0
Transfers from level 2	3	0	0
Ending balance	4	0	0
Auction Rate Securities [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	45	44	41
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)	(1)	1	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
Settlements	0	0	0
Transfers from level 2	0	0	0
Ending balance	$ 44	$ 45	$ 44

Fair Value Measurements - Debt

Fair Value Measurements - Debt (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 37,972	$ 38,649
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 41,785	$ 43,863

Fair Value Measurements - Pacif

Fair Value Measurements - PacifiCorp (Details) - USD ($) $ in Millions		Dec. 31, 2015		Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		$ 103		$ 75
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]	(16)		(40)
Assets, Fair Value Disclosure		2,692		2,193
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	119		115
Derivative Liability		(237)		(230)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		103	[1]	75
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		2,173		1,718
Derivative Liability		(13)		(18)
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		393		376
Derivative Liability		(296)		(284)
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		142		139
Derivative Liability		(47)		(43)
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]	(16)		(40)
Derivative assets		93		103
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	119		115
Derivative Liability		(223)		(220)
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		1
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(13)		(18)
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		16		48
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(283)		(274)
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		93		94
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(46)		(43)
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]	421		320
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]	421		320
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		136		137
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		136		137
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		37		48
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		28		30
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		9		25
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		3		4
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		75		28
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]	(3)		(11)
Derivative assets		9		18
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[3]	78		39
Derivative Liability		(70)		(75)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		75		28
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		9		25
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(148)		(114)
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		3		4
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		30
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		30
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
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
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		15
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		15
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 $103 million and $75 million as of December 31, 2015 and 2014, 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 $75 million and $28 million as of December 31, 2015 and 2014, respectively.
[4]	(2)Amounts are included in cash and cash equivalents, other current assets and other assets on the Consolidated Balance Sheets. Money market mutual funds are accounted for as available-for-sale securities and the fair value approximates cost.

Fair Value Measurements - Pa169

Fair Value Measurements - PacifiCorp - Debt (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 37,972	$ 38,649
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	41,785	43,863
PacifiCorp [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	7,114	6,985
PacifiCorp [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 8,210	$ 8,358

Fair Value Measurements - MEC (

Fair Value Measurements - MEC (Details) - USD ($) $ in Millions		Dec. 31, 2015		Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		$ 103		$ 75
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure		2,692		2,193
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[1]	(16)		(40)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	119		115
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		103	[1]	75
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		2,173		1,718
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		393		376
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		142		139
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]	(16)		(40)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[1]	119		115
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		1
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(13)		(18)
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		16		48
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(283)		(274)
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		93		94
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(46)		(43)
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		522		467
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[2]	(13)		(26)
Cash Collateral, Net Receivable (Payable), Offset Against Derivative Positions		28		47
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		438		381
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		53		62
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		44		50
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		28		47
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		13		17
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[2]	(13)		(26)
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(57)		(44)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	[2]	41		73
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		1
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(13)		(18)
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		8		18
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(61)		(87)
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		18		24
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement		(24)		(12)
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]	421		320
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]	421		320
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]	56		1
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]	56		1
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		133		136
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		133		136
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		133		136
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		133		136
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		2		1
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		2		1
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		2		1
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		2		1
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		39		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		39		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		39		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		39		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		1		2
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		1		2
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		1		2
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		1		2
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		3		2
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		3		2
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		3		2
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		3		2
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		45
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		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		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		45
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		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		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		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		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		239		238
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		239		238
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		239		238
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		239		238
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		1,244		886
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		1,244		886
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		6		5
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		6		5
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		136		137
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		136		137
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		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		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
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
[1]	Represents netting under master netting arrangements and a net cash collateral receivable of $103 million and $75 million as of December 31, 2015 and 2014, respectively.
[2]	(1)Represents netting under master netting arrangements and a net cash collateral receivable of $28 million and $47 million as of December 31, 2015 and 2014, 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, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative [Member] | MidAmerican Energy Company [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 12	$ (3)	$ 0
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	11	12	3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)	(7)	0	(2)
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net	(25)	6	0
Purchases	1	1	0
Settlements	2	(4)	(4)
Ending balance	(6)	12	(3)
Unrealized Gain (Loss) on Derivatives and Commodity Contracts	8	16	(5)
Auction Rate Securities [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	45	44	41
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)	(1)	1	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
Settlements	0	0	0
Ending balance	44	45	44
Auction Rate Securities [Member] | MidAmerican Energy Company [Member]
Fair Value, Assets (Liabilities), Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	26	23	21
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)	0	3	2
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
Settlements	0	0	0
Ending balance	$ 26	$ 26	$ 23

Fair Value Measurements - ME172

Fair Value Measurements - MEC - Debt (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 37,972	$ 38,649
MidAmerican Energy Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	4,271	4,056
Long-term Debt, Fair Value		4,581
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	41,785	$ 43,863
Fair Value, Inputs, Level 2 [Member] | MidAmerican Energy Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 4,636

Fair Value Measurements - MidAm

Fair Value Measurements - MidAmerican Funding - Debt (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 37,972	$ 38,649
MidAmerican Funding, LLC and Subsidiaries [Domain]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	4,597	4,381
Long-term Debt, Fair Value		5,012
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	41,785	$ 43,863
Fair Value, Inputs, Level 2 [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 5,051

Fair Value Measurements - NPC (

Fair Value Measurements - NPC (Details) - Fair Value, Measurements, Recurring [Member] - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
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	$ (13)	$ (18)
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	(283)	(274)
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	(46)	(43)
Nevada Power Company [Member] | Investment Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment Funds	5	20
Nevada Power Company [Member] | Investment Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment Funds	5	20
Nevada Power Company [Member] | Investment Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment Funds	0	0
Nevada Power Company [Member] | Investment Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment Funds	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	(22)	(30)
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	$ (22)	$ (30)

Fair Value Measurements - NPC -

Fair Value Measurements - NPC - Level 3 (Details) - Commodity [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
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	$ 47	$ 51	$ 60	$ 32
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net	(19)	5	1
Purchases	1	1	4
Settlements	2	1	(9)
Ending balance	47	51	60
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	(22)	(30)	(47)
Fair Value, Measurements with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included In Regulatory Assets and Liabilities, Net	0	9
Purchases	0	0
Settlements	8	8
Ending balance	$ (22)	$ (30)	$ (47)

Fair Value Measurements - NP176

Fair Value Measurements - NPC - Debt (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 37,972	$ 38,649
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	41,785	43,863
Nevada Power Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	2,788	3,034
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	$ 3,240	$ 3,712

Fair Value Measurements - SPPC

Fair Value Measurements - SPPC (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt	$ 37,972	$ 38,649
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt, Fair Value	41,785	43,863
Sierra Pacific Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt	1,165	1,164
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	$ 1,248	$ 1,301

Other, Net - MEC (Details)

Other, Net - MEC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	$ 39	$ 42	$ 51
MidAmerican Energy Company [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	5	10	16
MidAmerican Energy Company [Member] | Corporate Owned Life Insurance Income (Loss) [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	4	8	15
MidAmerican Energy Company [Member] | Gains (Losses) on Disposition of Assets [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	0	0	1
MidAmerican Energy Company [Member] | Other Income (Expense) [Member]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	$ 1	$ 2	$ 0

Other, Net - MidAmerican Fundin

Other, Net - MidAmerican Funding (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	$ 39	$ 42	$ 51
MidAmerican Funding, LLC and Subsidiaries [Domain]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	19	18	22
Corporate Owned Life Insurance Income (Loss) [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	4	8	15
Gains (Losses) on Disposition of Assets [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	13	0	1
Assets Leased to Others [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	1	5	2
Other Income (Expense) [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain]
Component of Other Income (Expense), Nonoperating [Line Items]
Other, net	$ 1	$ 5	$ 4

Income Taxes - Components of In

Income Taxes - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Current Federal Tax Expense (Benefit)	$ (929)	$ (1,872)	$ (985)
Current State and Local Tax Expense (Benefit)	29	(3)	(2)
Current foreign	84	129	121
Current Income Tax Expense (Benefit)	(816)	(1,746)	(866)
Deferred Federal Income Tax Expense (Benefit)	1,310	2,296	1,306
Deferred State and Local Income Tax Expense (Benefit)	(53)	37	(247)
Deferred foreign	17	11	(59)
Deferred Income Tax Expense (Benefit)	1,274	2,344	1,000
Other Tax Expense (Benefit)	(8)	(9)	(4)
Total income tax expense (benefit)	$ 450	$ 589	$ 130

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Effective Income Tax Rate (Details) - USD ($) $ in Millions	1 Months Ended				12 Months Ended
	Nov. 30, 2015	Apr. 30, 2015	Apr. 30, 2014	Jul. 31, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Abstract]
Federal statutory income tax rate					35.00%	35.00%	35.00%
Income tax credits					(11.00%)	(10.00%)	(14.00%)
State income tax, net of federal income tax benefit					(1.00%)	1.00%	(9.00%)
Income tax effect of foreign income					(7.00%)	(3.00%)	(6.00%)
Equity income (loss)					(2.00%)	(2.00%)	1.00%
Other, net					(2.00%)	(2.00%)	2.00%
Effective income tax rate					16.00%	23.00%	7.00%
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					$ 53	$ (37)	$ 247
Related Party Tax Expense [Abstract]
Income Taxes Receivable From (Payable To) Related Parties Current					286	1,100
NV Energy Transaction [Member]
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
Deferred state						$ 161
United Kingdom
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount					$ 39		$ 54
Corporate Income Tax Rate Enacted November 2015, Effective April 1, 2017 [Member] | United Kingdom
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
Corporate Income Tax Rate, Foreign	20.00%
Corporate Income Tax Rate Enacted November 2015, Effective April 1, 2017 19% [Member] | United Kingdom
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
Corporate Income Tax Rate, Foreign	19.00%
Corporate Income Tax Rate Enacted November 2015, Effective April 1, 2017 18% [Member] | United Kingdom
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
Corporate Income Tax Rate, Foreign	18.00%
Corporate Income Tax Rate Enacted July 2013, Effective April 1, 2014 [Member] | United Kingdom
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
Corporate Income Tax Rate, Foreign			21.00%	23.00%
Corporate Income Tax Rate Enacted July 2013, Effective April 1, 2015 [Member] | United Kingdom
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
Corporate Income Tax Rate, Foreign		20.00%

Income Taxes - Components of Ne

Income Taxes - Components of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Deferred income tax assets: [Abstract]
Federal, state and foreign carryforwards	$ 865	$ 781
Regulatory liabilities	834	812
AROs	317	249
Employee benefits	190	187
Derivative contracts	83	62
Other	815	781
Total deferred income tax assets	3,104	2,872
Valuation allowances	(35)	(23)
Total deferred income tax assets, net	3,069	2,849
Deferred income tax liabilities: [ Abstract]
Property-related items	(13,157)	(11,989)
Regulatory assets	(1,446)	(1,374)
Investments	(852)	(699)
Other	(299)	(301)
Total deferred income tax liabilities	(15,754)	(14,363)
Net deferred income tax liability	$ (12,685)	$ (11,514)

Income Taxes - Summary of Opera

Income Taxes - Summary of Operating Loss Carryforwards (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Operating Loss Carryforwards [Line Items]
Foreign carryforwards	$ 102
Deferred Tax Assets, Foreign Tax Credit, Years To Expiration	10 years
Federal [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 185	[1]
Deferred Tax Assets, Operating Loss Carryforwards	69
Deferred Tax Assets, Tax Credit Carryforwards	176	[2]
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	10,084	[1]
Deferred Tax Assets, Operating Loss Carryforwards	589
Deferred Tax Assets, Tax Credit Carryforwards	$ 31	[2]
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, 2016
Tax Credit Carryforward, Expiration Date	Dec. 31, 2016
Maximum [Member] | Federal [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2026
Maximum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2035
[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 net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2022.
[2]	Includes $102 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, 2015 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, 2015	Dec. 31, 2014
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	$ 220	$ 211
Additions based on tax positions related to the current year	3	11
Additions for tax positions of prior years	46	48
Reductions for tax positions of prior years	(58)	(50)
Statute of limitations	(6)	(1)
Settlements	(6)	0
Interest and penalties	(1)	1
Ending balance	198	220
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	163	188
Unrecognized tax benefits that would not impact the effective tax rate	$ 35	$ 32

Income Taxes - PacifiCorp - Com

Income Taxes - PacifiCorp - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Income Tax Expense (Benefit) Components [Line Items]
Current Federal Tax Expense (Benefit)	$ (929)	$ (1,872)	$ (985)
Current State and Local Tax Expense (Benefit)	29	(3)	(2)
Current Income Tax Expense (Benefit)	(816)	(1,746)	(866)
Deferred Federal Income Tax Expense (Benefit)	1,310	2,296	1,306
Deferred State and Local Income Tax Expense (Benefit)	(53)	37	(247)
Deferred Income Tax Expense (Benefit)	1,274	2,344	1,000
Other Tax Expense (Benefit)	(8)	(9)	(4)
Income tax expense	450	589	130
PacifiCorp [Member]
Schedule of Income Tax Expense (Benefit) Components [Line Items]
Current Federal Tax Expense (Benefit)	130	2	54
Current State and Local Tax Expense (Benefit)	26	10	13
Current Income Tax Expense (Benefit)	156	12	67
Deferred Federal Income Tax Expense (Benefit)	148	260	204
Deferred State and Local Income Tax Expense (Benefit)	29	43	29
Deferred Income Tax Expense (Benefit)	177	303	233
Other Tax Expense (Benefit)	(5)	(6)	(3)
Income tax expense	$ 328	$ 309	$ 297

Income Taxes - PacifiCorp - Rec

Income Taxes - PacifiCorp - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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%)	9.00%
Income tax credits	(11.00%)	(10.00%)	(14.00%)
Other, net	(2.00%)	(2.00%)	2.00%
Effective income tax rate	16.00%	23.00%	7.00%
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%)	(7.00%)	(7.00%)
Other, net	0.00%	0.00%	(1.00%)
Effective income tax rate	32.00%	31.00%	30.00%
Deferred Tax Assets, Tax Credit Carryforwards [Abstract]
Years Eligible For Renewable Energy Production Tax Credit	10 years

Income Taxes - PacifiCorp - 187

Income Taxes - PacifiCorp - Component of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities	$ 834	$ 812
AROs	317	249
Other	815	781
Total deferred income tax assets, net	3,069	2,849
Property-related items	(13,157)	(11,989)
Regulatory assets	(1,446)	(1,374)
Other	(299)	(301)
Total deferred income tax liabilities	(15,754)	(14,363)
Net deferred income tax liability	(12,685)	(11,514)
PacifiCorp [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities	374	362
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits	189	184
Deferred Tax Assets, Derivative Instruments And Unamortized Contract Values	94	79
Deferred Tax Assets, Operating Loss and Tax Credit Carryforwards, State and Local	68	68
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Contingencies	67	70
AROs	81	47
Other	88	92
Total deferred income tax assets, net	961	902
Property-related items	(5,030)	(4,780)
Regulatory assets	(639)	(647)
Other	(42)	(56)
Total deferred income tax liabilities	(5,711)	(5,483)
Net deferred income tax liability	$ (4,750)	$ (4,581)

Income Taxes - PacifiCorp - Sum

Income Taxes - PacifiCorp - Summary of Operating Loss Carryforwards (Details) - State and Local Jurisdiction [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 10,084	[1]
Deferred Tax Assets, Operating Loss Carryforwards	589
Deferred Tax Assets, Tax Credit Carryforwards	31	[2]
PacifiCorp [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	1,416
Deferred Tax Assets, Operating Loss Carryforwards	52
Deferred Tax Assets, Tax Credit Carryforwards	$ 16
Minimum [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2016
Tax Credit Carryforward, Expiration Date	Dec. 31, 2016
Minimum [Member] | PacifiCorp [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2016
Tax Credit Carryforward, Expiration Date	Dec. 31, 2016
Maximum [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2035
Maximum [Member] | PacifiCorp [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 net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2022.
[2]	Includes $102 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, 2015 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, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits	$ 198	$ 220	$ 211
PacifiCorp [Member]
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits	$ 13	$ 14

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, 2015	Dec. 31, 2014	Dec. 31, 2013
Components of Income Tax Expense (Benefit) [Line Items]
Current Federal Tax Expense (Benefit)	$ (929)	$ (1,872)	$ (985)
Current State and Local Tax Expense (Benefit)	29	(3)	(2)
Current Income Tax Expense (Benefit)	(816)	(1,746)	(866)
Deferred Federal Income Tax Expense (Benefit)	1,310	2,296	1,306
Deferred State and Local Income Tax Expense (Benefit)	(53)	37	(247)
Deferred Income Tax Expense (Benefit)	1,274	2,344	1,000
Other Tax Expense (Benefit)	(8)	(9)	(4)
Income tax (benefit) expense	450	589	130
MidAmerican Energy Company [Member]
Components of Income Tax Expense (Benefit) [Line Items]
Current Federal Tax Expense (Benefit)	(405)	(401)	(196)
Current State and Local Tax Expense (Benefit)	(10)	(3)	(10)
Current Income Tax Expense (Benefit)	(415)	(404)	(206)
Deferred Federal Income Tax Expense (Benefit)	281	299	101
Deferred State and Local Income Tax Expense (Benefit)	(6)	2	3
Deferred Income Tax Expense (Benefit)	275	301	104
Other Tax Expense (Benefit)	(1)	(1)	(1)
Income tax (benefit) expense	$ (141)	$ (104)	$ (103)

Income Taxes Income Taxes - 191

Income Taxes Income Taxes - MEC - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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	(11.00%)	(10.00%)	(14.00%)
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	1.00%	(1.00%)	9.00%
Other, net	(2.00%)	(2.00%)	2.00%
Effective income tax rate	16.00%	23.00%	7.00%
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	(65.00%)	(59.00%)	(70.00%)
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	(3.00%)	0.00%	(2.00%)
Effective Income Tax Rate Reconciliation Regulatory Differences	(12.00%)	(8.00%)	(3.00%)
Other, net	1.00%	(1.00%)	(2.00%)
Effective income tax rate	(44.00%)	(33.00%)	(42.00%)
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, 2015	Dec. 31, 2014
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities	$ 834	$ 812
Derivative contracts	83	62
AROs	317	249
Other	815	781
Total deferred income tax assets, net	3,069	2,849
Property-related items	(13,157)	(11,989)
Regulatory assets	(1,446)	(1,374)
Other	(299)	(301)
Total deferred income tax liabilities	(15,754)	(14,363)
Net deferred income tax liability	(12,685)	(11,514)
MidAmerican Energy Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities	327	332
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits	66	68
Derivative contracts	29	30
AROs	214	185
Other	59	59
Total deferred income tax assets, net	695	674
Property-related items	(3,321)	(2,945)
Regulatory assets	(418)	(366)
Other	(17)	(25)
Total deferred income tax liabilities	(3,756)	(3,336)
Net deferred income tax liability	$ (3,061)	$ (2,662)

Income Taxes - MEC - Summary of

Income Taxes - MEC - Summary of Operating Loss Carryforwards (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Operating Loss Carryforwards [Line Items]
Federal, state and foreign carryforwards		$ 865	$ 781
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	[1]	10,084
MidAmerican Energy Company [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Federal, state and foreign carryforwards		23
Operating Loss Carryforwards		$ 488
Minimum [Member] | MidAmerican Energy Company [Member]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss and Tax Credit Carry Forwards, Domestic Federal and State, ExpirationDate		2,016
Maximum [Member] | MidAmerican Energy Company [Member]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss and Tax Credit Carry Forwards, Domestic Federal and State, ExpirationDate		2,034
[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 net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2022.

Income Taxes - MEC - Net Unreco

Income Taxes - MEC - Net Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	$ 220	$ 211
Additions based on tax positions related to the current year	3	11
Additions for tax positions of prior years	46	48
Reductions for tax positions of prior years	(58)	(50)
Statute of limitations	(6)	(1)
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities	6	0
Interest and penalties	(1)	1
Ending balance	198	220
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	163	188
MidAmerican Energy Company [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	26	29
Additions based on tax positions related to the current year	3	6
Additions for tax positions of prior years	47	38
Unrecognized Tax Benefits, Decrease Resulting from Current Period Tax Positions	(6)	(4)
Reductions for tax positions of prior years	(46)	(40)
Statute of limitations	(5)	(3)
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities	6	0
Interest and penalties	3	0
Ending balance	10	$ 26
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	$ 26

Income Taxes - MidAmerican Fund

Income Taxes - MidAmerican Funding - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Components of Income Tax Expense (Benefit) [Line Items]
Current Federal Tax Expense (Benefit)	$ (929)	$ (1,872)	$ (985)
Current State and Local Tax Expense (Benefit)	29	(3)	(2)
Current Income Tax Expense (Benefit)	(816)	(1,746)	(866)
Deferred Federal Income Tax Expense (Benefit)	1,310	2,296	1,306
Deferred State and Local Income Tax Expense (Benefit)	(53)	37	(247)
Deferred Income Tax Expense (Benefit)	1,274	2,344	1,000
Other Tax Expense (Benefit)	(8)	(9)	(4)
Income tax (benefit) expense	450	589	130
MidAmerican Funding, LLC and Subsidiaries [Domain]
Components of Income Tax Expense (Benefit) [Line Items]
Current Federal Tax Expense (Benefit)	(408)	(404)	(200)
Current State and Local Tax Expense (Benefit)	(12)	(4)	(12)
Current Income Tax Expense (Benefit)	(420)	(408)	(212)
Deferred Federal Income Tax Expense (Benefit)	282	297	100
Deferred State and Local Income Tax Expense (Benefit)	(5)	2	3
Deferred Income Tax Expense (Benefit)	277	299	103
Other Tax Expense (Benefit)	(1)	(1)	(1)
Income tax (benefit) expense	$ (144)	$ (110)	$ (110)

Income Taxes Income Taxes - Mid

Income Taxes Income Taxes - MidAmerican Funding - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Effective Income Tax Rate Reconciliation [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Income tax credits	(11.00%)	(10.00%)	(14.00%)
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	1.00%	(1.00%)	9.00%
Other, net	(2.00%)	(2.00%)	2.00%
Effective income tax rate	16.00%	23.00%	7.00%
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	(67.00%)	(61.00%)	(75.00%)
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	(3.00%)	(1.00%)	(3.00%)
Effective Income Tax Rate Reconciliation Regulatory Differences	(12.00%)	(9.00%)	(3.00%)
Other, net	1.00%	(1.00%)	(2.00%)
Effective income tax rate	(46.00%)	(37.00%)	(48.00%)
Years Eligible For Renewable Energy Production Tax Credit	10 years

Income Taxes Income Taxes - 197

Income Taxes Income Taxes - MidAmerican Funding - Components of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities		$ 834	$ 812
Derivative contracts		83	62
AROs		317	249
Other		815	781
Total deferred income tax assets, net		3,069	2,849
Property-related items		(13,157)	(11,989)
Regulatory assets		(1,446)	(1,374)
Other		(299)	(301)
Total deferred income tax liabilities		(15,754)	(14,363)
Net deferred income tax liability		(12,685)	(11,514)
Federal, state and foreign carryforwards		865	781
MidAmerican Funding, LLC and Subsidiaries [Domain]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities		327	332
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits		66	68
Derivative contracts		29	30
AROs		214	185
Other		68	70
Total deferred income tax assets, net		704	685
Property-related items		(3,326)	(2,950)
Regulatory assets		(418)	(366)
Other		(16)	(25)
Total deferred income tax liabilities		(3,760)	(3,341)
Net deferred income tax liability		(3,056)	$ (2,656)
State and Local Jurisdiction [Member]
Deferred Tax Assets and Liabilities [Line Items]
Operating Loss Carryforwards	[1]	10,084
State and Local Jurisdiction [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain]
Deferred Tax Assets and Liabilities [Line Items]
Federal, state and foreign carryforwards		23
Operating Loss Carryforwards		$ 488
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		2,016
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		2,034
[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 net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2022.

Income Taxes - MidAmerican F198

Income Taxes - MidAmerican Funding - Net Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	$ 220	$ 211
Additions based on tax positions related to the current year	3	11
Additions for tax positions of prior years	46	48
Reductions for tax positions of prior years	(58)	(50)
Statute of limitations	(6)	(1)
Settlements	(6)	0
Interest and penalties	(1)	1
Ending balance	198	220
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	163	188
MidAmerican Funding, LLC and Subsidiaries [Domain]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	26	29
Additions based on tax positions related to the current year	4	6
Additions for tax positions of prior years	46	38
Unrecognized Tax Benefits, Decrease Resulting from Current Period Tax Positions	(6)	(4)
Reductions for tax positions of prior years	(46)	(40)
Statute of limitations	(5)	(3)
Settlements	(6)	0
Interest and penalties	3	0
Ending balance	10	$ 26
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	$ 27

Income Taxes - NPC - Components

Income Taxes - NPC - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Components of Income Tax Expense (Benefit) [Line Items]
Current federal tax expense (benefit)	$ (816)	$ (1,746)	$ (866)
Deferred federal income tax expense (benefit)	1,274	2,344	1,000
Other Tax Expense (Benefit)	(8)	(9)	(4)
Income tax expense	450	589	130
Nevada Power Company [Member]
Components of Income Tax Expense (Benefit) [Line Items]
Current federal tax expense (benefit)	0	0	(1)
Deferred federal income tax expense (benefit)	163	131	96
Other Tax Expense (Benefit)	(1)	(1)	(1)
Income tax expense	$ 162	$ 130	$ 94

Income Taxes - NPC - Reconcilia

Income Taxes - NPC - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Contingency [Line Items]
Federal statutory income tax rate	35.00%	35.00%	35.00%
Effective income tax rate	16.00%	23.00%	7.00%
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 Regulatory Differences	0.00%	0.00%	3.00%
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Merger Charges, Percent	1.00%	1.00%	1.00%
Effective income tax rate	36.00%	36.00%	39.00%

Income Taxes - NPC - Compone201

Income Taxes - NPC - Components of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Assets and Liabilities [Line Items]
Employee benefits	$ 190	$ 187
Regulatory liabilities	834	812
Other	815	781
Total deferred income tax assets	3,104	2,872
Valuation allowances	(35)	(23)
Total deferred income tax assets, net	3,069	2,849
Property-related items	(13,157)	(11,989)
Regulatory assets	(1,446)	(1,374)
Other	(299)	(301)
Total deferred income tax liabilities	(15,754)	(14,363)
Deferred Tax Liabilities, Net	12,685	11,514
MidAmerican Funding, LLC and Subsidiaries [Domain]
Deferred Tax Assets and Liabilities [Line Items]
Regulatory liabilities	327	332
Other	68	70
Total deferred income tax assets, net	704	685
Property-related items	(3,326)	(2,950)
Regulatory assets	(418)	(366)
Other	(16)	(25)
Total deferred income tax liabilities	(3,760)	(3,341)
Deferred Tax Liabilities, Net	3,056	2,656
Nevada Power Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Deferred Tax Assets, Operating Loss and Credit Carryforwards, Federal	15	158
Deferred Tax Assets, Tax Deferred Expense, Leases	174	178
Employee benefits	30	22
Regulatory liabilities	47	37
Other	39	57
Total deferred income tax assets	305	452
Valuation allowances	(5)	(2)
Total deferred income tax assets, net	300	450
Property-related items	(1,242)	(1,175)
Regulatory assets	(275)	(341)
Deferred Tax Liabilities, Tax Deferred Expense, Leases	(169)	(174)
Other	(19)	(29)
Total deferred income tax liabilities	(1,705)	(1,719)
Deferred Tax Liabilities, Net	$ 1,405	$ 1,269

Income Taxes - NPC - Summary of

Income Taxes - NPC - Summary of Operating Loss Carryforwards (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Nevada Power Company [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 4
Deferred Tax Assets, Operating Loss Carryforwards	1
Deferred Tax Assets, Tax Credit Carryforwards	14
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	10,084	[1]
Deferred Tax Assets, Operating Loss Carryforwards	589
Deferred Tax Assets, Tax Credit Carryforwards	$ 31	[2]
Minimum [Member] | Nevada Power Company [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2031
Tax Credit Carryforward, Expiration Date	Dec. 31, 2016
Minimum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2016
Tax Credit Carryforward, Expiration Date	Dec. 31, 2016
Maximum [Member] | Nevada Power Company [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2035
Tax Credit Carryforward, Expiration Date	Dec. 31, 2035
Maximum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2035
[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 net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2022.
[2]	Includes $102 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, 2015 the statute of limitation had not begun on the foreign tax credit carryforwards.

Income Taxes - SPPC - Component

Income Taxes - SPPC - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Components of Income Tax Expense (Benefit) [Line Items]
Current federal tax expense (benefit)	$ (816)	$ (1,746)	$ (866)
Deferred Federal Income Tax Expense (Benefit)	1,310	2,296	1,306
Deferred State and Local Income Tax Expense (Benefit)	(53)	37	(247)
Deferred Income Tax Expense (Benefit)	1,274	2,344	1,000
Other Tax Expense (Benefit)	(8)	(9)	(4)
Income tax expense	450	589	130
Sierra Pacific Power Company [Member]
Components of Income Tax Expense (Benefit) [Line Items]
Current federal tax expense (benefit)	0	0	(2)
Deferred Federal Income Tax Expense (Benefit)	48	48	38
Deferred State and Local Income Tax Expense (Benefit)	0	0	(2)
Deferred Income Tax Expense (Benefit)	48	48	36
Other Tax Expense (Benefit)	(1)	(1)	(1)
Income tax expense	$ 47	$ 47	$ 33

Income Taxes - SPPC - Reconcili

Income Taxes - SPPC - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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	16.00%	23.00%	7.00%
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	0.00%	0.00%	1.00%
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Merger Charges, Percent	1.00%	1.00%	1.00%
Other, net	0.00%	(1.00%)	0.00%
Effective income tax rate	36.00%	35.00%	37.00%

Income Taxes - SPPC - Compon205

Income Taxes - SPPC - Components of Net Deferred Income Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Assets and Liabilities [Line Items]
Employee benefits	$ 190	$ 187
Regulatory liabilities	834	812
Other	815	781
Total deferred income tax assets	3,104	2,872
Property-related items	(13,157)	(11,989)
Regulatory assets	(1,446)	(1,374)
Other	(299)	(301)
Total deferred income tax liabilities	(15,754)	(14,363)
Net deferred income tax liability	(12,685)	(11,514)
Sierra Pacific Power Company [Member]
Deferred Tax Assets and Liabilities [Line Items]
Deferred Tax Assets, Operating Loss and Credit Carryforwards, Federal	39	56
Employee benefits	25	22
Regulatory liabilities	19	21
Deferred Tax Assets, Tax Deferred Expense, Leases	13	9
Deferred Tax Assets, Customer Advances	8	7
Other	12	15
Total deferred income tax assets	116	130
Property-related items	(538)	(478)
Regulatory assets	(121)	(147)
Deferred Tax Liabilities, Tax Deferred Expense, Leases	(13)	(9)
Other	(14)	(20)
Total deferred income tax liabilities	(686)	(654)
Net deferred income tax liability	$ (570)	$ (524)

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, 2015USD ($)
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 95
Deferred Tax Assets, Operating Loss Carryforwards	33
Deferred Tax Assets, Tax Credit Carryforwards	$ 5
Minimum [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2031
Tax Credit Carryforward, Expiration Date	Dec. 31, 2016
Maximum [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2035
Tax Credit Carryforward, Expiration Date	Dec. 31, 2035

Supplemental Cash Flow Discl207

Supplemental Cash Flow Disclosures (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Supplemental Cash Flow Information [Abstract]
Interest paid, net of amounts capitalized		$ 1,764	$ 1,585	$ 1,073
Income Taxes Paid, Net	[1]	(1,666)	(635)	(1,105)
Related Party Transaction, Cash Received for Income Taxes, Net		1,800	764	1,200
Capital Expenditures Incurred but Not yet Paid		$ 718	$ 1,143	$ 661
[1]	Includes $1.8 billion, $764 million and $1.2 billion of income taxes received from Berkshire Hathaway in 2015, 2014 and 2013, respectively.

Supplemental Cash Flow Discl208

Supplemental Cash Flow Disclosures - PacifiCorp (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		$ 1,764	$ 1,585	$ 1,073
Income Taxes Paid, Net	[1]	(1,666)	(635)	(1,105)
Accruals related to property, plant and equipment additions		718	1,143	661
PacifiCorp [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		342	340	340
Income Taxes Paid, Net		40	161	120
Accruals related to property, plant and equipment additions		147	140	157
Accounts receivable related to property, plant and equipment sales		$ 40	$ 0	$ 0
[1]	Includes $1.8 billion, $764 million and $1.2 billion of income taxes received from Berkshire Hathaway in 2015, 2014 and 2013, respectively.

Supplemental Cash Flow Discl209

Supplemental Cash Flow Disclosures - MEC (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Income Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		$ 1,764	$ 1,585	$ 1,073
Income taxes received, net	[1]	1,666	635	1,105
Accruals related to property, plant and equipment additions		718	1,143	661
MidAmerican Energy Company [Member]
Condensed Income Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		154	144	109
Income taxes received, net		629	149	36
Accruals related to property, plant and equipment additions		$ 249	$ 128	$ 117
[1]	Includes $1.8 billion, $764 million and $1.2 billion of income taxes received from Berkshire Hathaway in 2015, 2014 and 2013, respectively.

Supplemental Cash Flow Discl210

Supplemental Cash Flow Disclosures - MidAmerican Funding (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		$ 1,764	$ 1,585	$ 1,073
Income taxes received, net	[1]	1,666	635	1,105
Accruals related to property, plant and equipment additions		718	1,143	661
MidAmerican Funding, LLC and Subsidiaries [Domain]
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized		177	167	132
Income taxes received, net		630	153	42
Accruals related to property, plant and equipment additions		$ 249	$ 128	$ 117
[1]	Includes $1.8 billion, $764 million and $1.2 billion of income taxes received from Berkshire Hathaway in 2015, 2014 and 2013, respectively.

Supplemental Cash Flow Discl211

Supplemental Cash Flow Disclosures - NPC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized	$ 1,764	$ 1,585	$ 1,073
Accruals related to property, plant and equipment additions	718	1,143	661
Nevada Power Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized	186	194	209
Accruals related to property, plant and equipment additions	51	30	25
Capital and Financial Lease Obligations Incurred	$ (5)	$ 7	$ 419

Supplemental Cash Flow Discl212

Supplemental Cash Flow Disclosures - SPPC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized	$ 1,764	$ 1,585	$ 1,073
Accruals related to property, plant and equipment additions	718	1,143	661
Sierra Pacific Power Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Interest paid, net of amounts capitalized	54	54	59
Accruals related to property, plant and equipment additions	24	31	37
Capital and Financial Lease Obligations Incurred	$ 13	$ 1	$ 22

Related Party Transactions - Pa

Related Party Transactions - PacifiCorp (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Income Taxes Receivable From (Payable To) Related Parties Current	$ 286	$ 1,100
Related Party Transaction, Cash Received for Income Taxes, Net	1,800	764	$ 1,200
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	17
Due to Affiliate, Current	2	1
Related Party Transaction, Expense Reimbursement	7	10	9
Due from Affiliate, Current	1	7
PacifiCorp [Member] | Subsidiary of Common Parent [Member]
Related Party Transaction [Line Items]
Due to Affiliate, Current	1	1
Purchases from Related Party	8	7	5
Revenue from Related Parties	2	5	0
PacifiCorp [Member] | BNSF Railway Company [Member]
Related Party Transaction [Line Items]
Due to Affiliate, Current	1	3
Purchases from Related Party	39	39	32
PacifiCorp [Member] | MEHC Insurance Services Ltd. [Member]
Related Party Transaction [Line Items]
Due from Affiliate, Current	0	2
Related Party Transaction, Proceeds From Insurance Claims	2	0	1
PacifiCorp [Member] | BHE [Member]
Related Party Transaction [Line Items]
Income Taxes Receivable From (Payable To) Related Parties Current	17	133
Related Party Transaction, Cash Received for Income Taxes, Net	(40)	(161)	(120)
PacifiCorp [Member] | Bridger Coal Company [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expense Reimbursement	19	3	2
Due from Affiliate, Current	4	4
PacifiCorp [Member] | Equity Method Investee [Member]
Related Party Transaction [Line Items]
Due to Affiliate, Current	16	19
Purchases from Related Party	$ 181	$ 146	$ 152

Related Party Transactions R214

Related Party Transactions Related Party Transactions - MEC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Income Taxes Receivable From (Payable To) Related Parties Current	$ 286	$ 1,100
Related Party Transaction, Cash Received for Income Taxes, Net	1,800	764	$ 1,200
MidAmerican Energy Company [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expense Reimbursement	46	58	38
Due from Affiliate, Current	5	12
Due to Affiliate, Current	13	12
Due from Affiliate, Noncurrent	10	13
Due to Affiliate, Noncurrent	29	30
MidAmerican Energy Company [Member] | BHE [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	7	8	10
Income Taxes Receivable From (Payable To) Related Parties Current	102	299
Related Party Transaction, Cash Received for Income Taxes, Net	629	149	36
MidAmerican Energy Company [Member] | Northern Natural Gas and BNSF Railway Company [Member]
Related Party Transaction [Line Items]
Purchases from Related Party	$ 165	$ 144	$ 155

Related Party Transactions - Mi

Related Party Transactions - MidAmerican Funding (Details) $ in Millions		12 Months Ended
		Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Related Party Transaction [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	[1]	$ 6,421	$ 6,696
Income Taxes Receivable From (Payable To) Related Parties Current		286	1,100
Related Party Transaction, Cash Received for Income Taxes, Net		1,800	764	$ 1,200
MidAmerican Funding, LLC and Subsidiaries [Domain]
Related Party Transaction [Line Items]
Notes Payable, Related Parties, Current		$ 139	136
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	37	28
Due from Affiliate, Current		7	7
Due to Affiliate, Current		12	12
Due from Affiliate, Noncurrent		10	13
Due to Affiliate, Noncurrent		29	30
MidAmerican Funding, LLC and Subsidiaries [Domain] | BHE [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party		7	8	10
Income Taxes Receivable From (Payable To) Related Parties Current		102	296
Related Party Transaction, Cash Received for Income Taxes, Net		631	154	42
MidAmerican Funding, LLC and Subsidiaries [Domain] | Northern Natural Gas and BNSF Railway Company [Member]
Related Party Transaction [Line Items]
Purchases from Related Party		165	144	$ 155
Revolving Credit Arrangement, $300 million [Member] | Line of Credit [Member] | MHC, Inc. [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain] | BHE [Member]
Related Party Transaction [Line Items]
Line of Credit Arrangement Offered to Affiliate, Maximum Amount Available		300
Notes Payable, Related Parties, Current		$ 139	$ 136
Debt, Weighted Average Interest Rate		0.494%	0.408%
Revolving Credit Arrangement, $100 million [Member] | Line of Credit [Member] | MHC, Inc. [Member] | MidAmerican Funding, LLC and Subsidiaries [Domain] | 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) - Nevada Power Company [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Kern River [Member]
Related Party Transaction [Line Items]
Purchases from Related Party	$ 68	$ 68	$ 68
Due to Affiliate, Current	5	5
Sierra Pacific Power Company [Member]
Related Party Transaction [Line Items]
Due to Affiliate	0	0
Due from Affiliates	6	5
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	16	16	22
Related Party Transaction, Expense Reimbursement	22	20	24
NV Energy, Inc. [Member]
Related Party Transaction [Line Items]
Due to Affiliate	40	33
Due from Affiliates	0	0
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	12	19	45
Related Party Transaction, Expense Reimbursement	1	1	0
Electric Distribution [Member] | PacifiCorp [Member]
Related Party Transaction [Line Items]
Purchases from Related Party	2	5	2
Revenue from Related Parties	3	3	3
Due to Affiliate	0	4
Due from Affiliates	0	0
Electric Distribution [Member] | Sierra Pacific Power Company [Member]
Related Party Transaction [Line Items]
Purchases from Related Party	2	8	1
Revenue from Related Parties	69	33	$ 36
Due to Affiliate	1	0
Due from Affiliates	$ 15	$ 7

Related Party Transactions - SP

Related Party Transactions - SPPC (Details) - Sierra Pacific Power Company [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
NV Energy, Inc. [Member]
Related Party Transaction [Line Items]
Due from Affiliates	$ 0	$ 0
Due to Affiliate	21	20
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	6	9	$ 19
Nevada Power Company [Member]
Related Party Transaction [Line Items]
Due from Affiliates	0	0
Due to Affiliate	6	5
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	22	20	0
Related Party Transaction, Expense Reimbursement	16	16	0
Electric Distribution [Member] | Nevada Power Company [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	2	8	1
Purchases from Related Party	69	33	$ 36
Due from Affiliates	1	4
Due to Affiliate	$ 15	$ 7

Employee Benefit Plans - Net Pe

Employee Benefit Plans - Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	$ 33	$ 36	$ 24
Defined Benefit Plan, Interest Cost	121	131	87
Defined Benefit Plan, Expected Return on Plan Assets	(169)	(164)	(119)
Defined Benefit Plan Net Amortization	53	44	58
Defined Benefit Plan, Net Periodic Benefit Cost	38	47	50
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	11	14	14
Defined Benefit Plan, Interest Cost	31	46	33
Defined Benefit Plan, Expected Return on Plan Assets	(45)	(53)	(44)
Defined Benefit Plan Net Amortization	(11)	(3)	6
Defined Benefit Plan, Net Periodic Benefit Cost	(14)	4	9
UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	24	24	22
Defined Benefit Plan, Interest Cost	79	95	85
Defined Benefit Plan, Expected Return on Plan Assets	(116)	(124)	(101)
Defined Benefit Plan Net Amortization	62	51	53
Defined Benefit Plan, Net Periodic Benefit Cost	$ 49	$ 46	$ 59

Employee Benefit Plans - Funded

Employee Benefit Plans - Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2015	Dec. 31, 2014
Domestic Pension Plans [Member]
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Fair Value of Plan Assets	$ 2,718	$ 2,711	$ 2,711	$ 2,489	$ 2,718
Defined Benefit Plan, Benefit Obligation	3,119	2,821	2,821	2,934	3,119
Defined Benefit Plan, Funded Status of Plan				(445)	(401)
Other assets				7	12
Other current liabilities				(15)	(14)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(437)	(399)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(445)	(401)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	2,718	2,711
Defined Benefit Plan, Contributions by Employer	13	37
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actual Return on Plan Assets	(17)	188
Defined Benefit Plan, Settlements, Plan Assets	(23)	0
Defined Benefit Plan, Benefits Paid	(202)	(218)
Ending balance	2,489	2,718	2,711
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	3,119	2,821
Defined Benefit Plan, Service Cost	33	36	24
Defined Benefit Plan, Interest Cost	121	131	87
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actuarial Gain (Loss)	(110)	349
Defined Benefit Plan, Plan Amendments	(4)	0
Defined Benefit Plan, Settlements, Benefit Obligation	(23)	0
Benefits Paid	(202)	(218)
Ending balance	2,934	3,119	2,821
Defined Benefit Plan, Accumulated Benefit Obligation				2,906	3,086
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				1,811	1,987
Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets, Aggregate Benefit Obligation				2,263	2,401
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation				2,244	2,380
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Fair Value of Plan Assets	858	852	852	662	858
Defined Benefit Plan, Benefit Obligation	936	987	987	740	936
Defined Benefit Plan, Funded Status of Plan				(78)	(78)
Other assets				15	10
Other current liabilities				0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(93)	(88)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(78)	(78)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	858	852
Defined Benefit Plan, Contributions by Employer	2	2
Defined Benefit Plan, Contributions by Plan Participants	9	11
Defined Benefit Plan, Actual Return on Plan Assets	0	54
Defined Benefit Plan, Settlements, Plan Assets	(150)	0
Defined Benefit Plan, Benefits Paid	(57)	(61)
Ending balance	662	858	852
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	936	987
Defined Benefit Plan, Service Cost	11	14	14
Defined Benefit Plan, Interest Cost	31	46	33
Defined Benefit Plan, Contributions by Plan Participants	9	11
Defined Benefit Plan, Actuarial Gain (Loss)	(43)	(61)
Defined Benefit Plan, Plan Amendments	3	0
Defined Benefit Plan, Settlements, Benefit Obligation	(150)	0
Benefits Paid	(57)	(61)
Ending balance	740	936	987
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	598
Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets, Aggregate Benefit Obligation				505	686
Domestic Other Postretirement Plans [Member] | PacifiCorp [Member]
Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets [Abstract]
Defined Benefit Plan, Amount To Be Transferred				150
UK Pension Plans [Member]
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Fair Value of Plan Assets	2,368	2,177	2,177	2,276	2,368
Defined Benefit Plan, Benefit Obligation	2,279	2,185	2,185	2,142	2,279
Defined Benefit Plan, Funded Status of Plan				134	89
Other assets				134	89
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	2,368	2,177
Defined Benefit Plan, Contributions by Employer	77	89
Defined Benefit Plan, Contributions by Plan Participants	2	2
Defined Benefit Plan, Actual Return on Plan Assets	48	337
Defined Benefit Plan, Benefits Paid	(91)	(92)
Foreign Currency Exchange Rate Changes	(128)	(145)
Ending balance	2,276	2,368	2,177
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	2,279	2,185
Defined Benefit Plan, Service Cost	24	24	22
Defined Benefit Plan, Interest Cost	79	95	85
Defined Benefit Plan, Contributions by Plan Participants	2	2
Defined Benefit Plan, Actuarial Gain (Loss)	(30)	205
Benefits Paid	(91)	(92)
Foreign currency exchange rate changes	(121)	(140)
Ending balance	$ 2,142	$ 2,279	$ 2,185
Defined Benefit Plan, Accumulated Benefit Obligation				1,891	2,019
Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount				$ 228	$ 247

Employee Benefit Plans - Unreco

Employee Benefit Plans - Unrecognized Amounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	$ 27
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	61
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(27)
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	0
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	34
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			$ 768	$ 757
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax			(25)	(31)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax			(2)	(3)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	723	$ 441	741	723
Beginning balance	723	441
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	75	326
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	11
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(53)	(44)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	18	282
Ending balance	741	723
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	58
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(11)
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	46
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			97	108
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax			(68)	(87)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax			8	2
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	23	83	37	23
Beginning balance	23	83
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	0	(63)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	16
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	11	3
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	14	(60)
Ending balance	37	23
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	(16)
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	(12)
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			592	655
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	48
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	710	490	729	710
Beginning balance	710	490
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	76	258
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(4)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(53)	(38)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	19	220
Ending balance	729	710
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	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	37	99	49	37
Beginning balance	37	99
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(1)	(64)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	3
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	10	2
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	12	(62)
Ending balance	49	37
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	(6)	(58)	(1)	(6)
Beginning balance	(6)	(58)
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	5	52
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	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	5	52
Ending balance	(1)	(6)
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
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	(14)	(16)	(12)	(14)
Beginning balance	(14)	(16)
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	2	2
Ending balance	(12)	(14)
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	19	9	13	19
Beginning balance	19	9
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	(6)	16
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	0
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	0	(6)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(6)	10
Ending balance	13	19
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] | UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	655	751	$ 592	$ 655
Beginning balance	655	751
Defined Benefit Plan, Net Unamortized Gain (Loss) Arising During Period, Before Tax	38	(8)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(62)	(51)
Foreign currency exchange rate changes	(39)	(37)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(63)	(96)
Ending balance	592	$ 655
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	(4)
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	4
Defined Benefit Plan Amount Not Yet Recognized In Net Periodic Benefit Cost, Category [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	3
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)

Employee Benefit Plans - Plan A

Employee Benefit Plans - Plan Assumptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.70%	8.00%
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	(1)
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	5
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	$ (5)
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.43%	4.00%	4.81%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.75%	2.75%	3.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.00%	4.81%	4.03%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.88%	6.86%	7.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.75%	3.00%	3.00%
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.33%	3.88%	4.82%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.93%	4.82%	4.01%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.00%	7.34%	7.44%
UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.70%	3.60%	4.40%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.90%	2.80%	3.15%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Expected Rate Of Future Price Inflation	2.90%	2.80%	3.15%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.60%	4.40%	4.40%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	5.60%	6.10%	5.70%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.80%	3.15%	2.80%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Rate of Future Price Inflation	2.80%	3.15%	2.80%

Employee Benefit Plans - Contri

Employee Benefit Plans - Contributions and Benefit Payments (Details) - 12 months ended Dec. 31, 2015 £ 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	$ 34
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	221
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	224
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	226
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	224
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	225
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	1,054
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	56
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	57
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	58
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	58
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	61
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	272
UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year | £		£ 40
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	88
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	90
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	92
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	95
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	97
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	$ 522

Employee Benefit Plans - Asset

Employee Benefit Plans - Asset Allocations (Details)		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Domestic Pension Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of Investment Funds Comprised Of Debt Securities		34.00%	39.00%
Percentage of Investment Funds Comprised Of Equity Securitites		66.00%	61.00%
Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of Investment Funds Comprised Of Debt Securities		37.00%	37.00%
Percentage of Investment Funds Comprised Of Equity Securitites		63.00%	63.00%
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	[1]	50.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	55.00%
UK Pension Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations Range Minimum	[1]	35.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[1]	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	[2]	33.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[2]	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	[2]	53.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[2]	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	[2]	33.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[2]	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	[2]	61.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[2]	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	[2]	20.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[2]	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	[2]	60.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[2]	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	[2]	25.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[2]	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	[2]	50.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[2]	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	[2]	53.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[2]	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	[2]	23.00%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	[2]	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	[2]	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	[2]	6000.00%
[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.
[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.

Employee Benefit Plans - Fair V

Employee Benefit Plans - Fair Value Measurements (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Actual Return on Plan Assets		$ (17)		$ 188
Defined Benefit Plan, Settlements, Plan Assets		(23)		0
Defined Benefit Plan, Fair Value of Plan Assets		2,489		2,718		$ 2,711
Domestic Pension Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	1,007		1,302
Domestic Pension Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	1,370		1,306
Domestic Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	112		110
Domestic Pension Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		31		69
Domestic 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	[1]	0		15
Domestic 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	[1]	31		54
Domestic 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	[1]	0		0
Domestic Pension Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		155		166
Domestic Pension 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]	155		166
Domestic Pension 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 Pension 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 Pension Plans [Member] | Foreign Government Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4		11
Domestic Pension Plans [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
Domestic Pension Plans [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]	4		11
Domestic Pension Plans [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
Domestic Pension Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		335		268
Domestic 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	[1]	0		0
Domestic 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	[1]	335		268
Domestic 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	[1]	0		0
Domestic Pension Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		25		27
Domestic Pension 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 Pension 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]	25		27
Domestic Pension 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 Pension Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		154		94
Domestic Pension 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 Pension 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]	154		94
Domestic Pension 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 Pension Plans [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		586		698
Domestic Pension 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]	586		698
Domestic Pension 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 Pension 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 Pension Plans [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		122		122
Domestic Pension 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]	122		122
Domestic Pension 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 Pension 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 Pension Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	$ 965		$ 1,153
Percentage of Investment Funds Comprised Of Equity Securitites		66.00%		61.00%
Percentage of Investment Funds Comprised Of Debt Securities		34.00%		39.00%
Percentage Of Investment Funds Invested in United States Securities		58.00%		64.00%
Percentage Of Investment Funds Invested In International Securities		42.00%		36.00%
Domestic 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	[1],[2]	$ 144		$ 301
Domestic 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	[1],[2]	821		852
Domestic 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	[1],[2]	0		0
Domestic Pension Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	65		70
Domestic Pension Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[3]	0		0
Domestic Pension Plans [Member] | Limited Partnership Interests [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 Pension Plans [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		65	[1],[3]	70	[1],[3]	86	$ 96
Domestic Pension Plans [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		47		40
Domestic 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	[1]	0		0
Domestic 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	[1]	0		0
Domestic 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		47	[1]	40	[1]	31	26
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Actual Return on Plan Assets		0		54
Defined Benefit Plan, Settlements, Plan Assets		(150)		0
Defined Benefit Plan, Fair Value of Plan Assets		662		858		852
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	[4]	401		613
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	[4]	257		240
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	[4]	4		5
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		14	[5]	146
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]	12	[5]	145
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	[4]	2	[5]	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	[4]	0	[5]	0
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		18		17
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	[4]	18		17
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	[4]	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	[4]	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		33		34
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	[4]	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	[4]	33		34
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	[4]	0		0
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		41		43
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	[4]	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	[4]	41		43
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	[4]	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		28		31
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	[4]	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	[4]	28		31
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	[4]	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		216		243
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	[4]	216		243
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	[4]	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	[4]	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		6		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	[4]	6		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	[4]	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	[4]	0		0
Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[6]	$ 302		$ 333
Percentage of Investment Funds Comprised Of Equity Securitites		63.00%		63.00%
Percentage of Investment Funds Comprised Of Debt Securities		37.00%		37.00%
Percentage Of Investment Funds Invested in United States Securities		70.00%		69.00%
Percentage Of Investment Funds Invested In International Securities		30.00%		31.00%
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	[4],[6]	$ 149		$ 202
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	[4],[6]	153		131
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	[4],[6]	0		0
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[7]	4		5
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4],[7]	0		0
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4],[7]	0		0
Domestic Other Postretirement Plans [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		4	[4],[7]	5	[4],[7]	6	7
UK Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Actual Return on Plan Assets		48		337
Defined Benefit Plan, Fair Value of Plan Assets		2,276		2,368		2,177
UK Pension Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[8]	579		609
UK Pension Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[8]	1,493		1,560
UK Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[8]	204		199
UK Pension Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		46		43
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	[8]	46		43
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	[8]	0		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	[8]	0		0
UK Pension Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				0
UK Pension 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	[8]			0
UK Pension 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	[8]			0
UK Pension 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	[8]			0
UK Pension Plans [Member] | United Kingdom Government Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		424		452
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		424	[8]	452
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	[8]	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	[8]	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		14
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	[8]	0		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	[8]	13		14
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	[8]	0		0
UK Pension Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		186		196
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	[8]	0		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	[8]	186		196
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	[8]	0		0
UK Pension Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[9]	$ 1,403		1,464
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	[8],[9]	$ 109		114
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	[8],[9]	1,294		1,350
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	[8],[9]	0		0
UK Pension Plans [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		204		199
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	[8]	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	[8]	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		204	[8]	199	[8]	179	163
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Actual Return on Plan Assets		0		53
Defined Benefit Plan, Settlements, Plan Assets		0		0
Defined Benefit Plan, Fair Value of Plan Assets		1,043		1,146		1,171
PacifiCorp [Member] | Domestic Pension Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		527		736
PacifiCorp [Member] | Domestic Pension Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		451		340
PacifiCorp [Member] | Domestic Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		65		70
PacifiCorp [Member] | Domestic Pension Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		10		8
PacifiCorp [Member] | Domestic 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		0		0
PacifiCorp [Member] | Domestic 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		10		8
PacifiCorp [Member] | Domestic 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		0		0
PacifiCorp [Member] | Domestic Pension Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		19		15
PacifiCorp [Member] | Domestic Pension 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		19		15
PacifiCorp [Member] | Domestic Pension 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 Pension 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 Pension Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		42		53
PacifiCorp [Member] | Domestic 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		0		0
PacifiCorp [Member] | Domestic 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		42		53
PacifiCorp [Member] | Domestic 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		0		0
PacifiCorp [Member] | Domestic Pension Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5		8
PacifiCorp [Member] | Domestic Pension 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 Pension 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		5		8
PacifiCorp [Member] | Domestic Pension 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 Pension Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		43		48
PacifiCorp [Member] | Domestic Pension 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 Pension 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		43		48
PacifiCorp [Member] | Domestic Pension 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 Pension Plans [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		408		488
PacifiCorp [Member] | Domestic Pension 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		408		488
PacifiCorp [Member] | Domestic Pension 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 Pension 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 Pension Plans [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		17		16
PacifiCorp [Member] | Domestic Pension 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		17		16
PacifiCorp [Member] | Domestic Pension 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 Pension 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 Pension Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 434		$ 440
Percentage of Investment Funds Comprised Of Equity Securitites		53.00%		50.00%
Percentage of Investment Funds Comprised Of Debt Securities		47.00%		50.00%
Percentage Of Investment Funds Invested in United States Securities		40.00%		43.00%
Percentage Of Investment Funds Invested In International Securities		60.00%		57.00%
PacifiCorp [Member] | Domestic 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		$ 83		$ 217
PacifiCorp [Member] | Domestic 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		351		223
PacifiCorp [Member] | Domestic 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		0		0
PacifiCorp [Member] | Domestic Pension Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		65		70
PacifiCorp [Member] | Domestic Pension Plans [Member] | Limited Partnership Interests [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 Pension Plans [Member] | Limited Partnership Interests [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 Pension Plans [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		65		70		86	96
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Actual Return on Plan Assets		1		25
Defined Benefit Plan, Settlements, Plan Assets		(150)		0
Defined Benefit Plan, Fair Value of Plan Assets		305		482		486
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		347
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		157		130
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		4		5
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		139
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		139
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		0
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		9		8
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		9		8
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		15		18
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		15		18
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		1		2
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		1		2
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		14		16
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		14		16
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		95		112
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		95		112
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		$ 158		$ 178
Percentage of Investment Funds Comprised Of Equity Securitites		61.00%		63.00%
Percentage of Investment Funds Comprised Of Debt Securities		39.00%		37.00%
Percentage Of Investment Funds Invested in United States Securities		67.00%		64.00%
Percentage Of Investment Funds Invested In International Securities		33.00%		36.00%
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		$ 84
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		126		94
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
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		4		5
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [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] | Limited Partnership Interests [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] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 4		$ 5		$ 6	$ 7
[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 66% and 34%, respectively, for 2015 and 61% and 39%, respectively, for 2014. Additionally, these funds are invested in United States and international securities of approximately 58% and 42%, respectively, for 2015 and 64% and 36%, respectively, for 2014.
[3]	Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
[4]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[5]	In December 2014, PacifiCorp began to migrate funds to cash and cash equivalents in anticipation of the $150 million to be transferred to a fund managed by the UMWA in May 2015 as a result of the other postretirement settlement. Remaining investments were rebalanced to align to PacifiCorp's target investment allocations.
[6]	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 2015 and 63% and 37%, respectively, for 2014. Additionally, these funds are invested in United States and international securities of approximately 70% and 30%, respectively, for 2015 and 69% and 31%, respectively, for 2014.
[7]	Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
[8]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[9]	Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 44% and 56% for both 2015 and 2014.

Employee Benefit Plans - Level

Employee Benefit Plans - Level 3 Rollforward (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Domestic Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		$ 2,718		$ 2,711
Ending balance		2,489		2,718		$ 2,711
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]	110
Ending balance	[1]	112		110
Domestic Pension Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	[2]	70
Ending balance	[2]	65		70
Domestic Pension Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		70	[1],[2]	86		96
Defined Benefit Plan, Actual Return on Plan Assets Still Held		5		(1)		16
Defined Benefit Plan, Purchases, Sales, and Settlements		(10)		(15)		(26)
Ending balance		65	[1],[2]	70	[1],[2]	86
Domestic Pension Plans [Member] | Real Estate Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		40
Ending balance		47		40
Domestic 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		40	[1]	31		26
Defined Benefit Plan, Actual Return on Plan Assets Still Held		7		4		5
Defined Benefit Plan, Purchases, Sales, and Settlements		0		5		0
Ending balance		47	[1]	40	[1]	31
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		858		852
Ending balance		662		858		852
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	[3]	5
Ending balance	[3]	4		5
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	[4]	5
Ending balance	[4]	4		5
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		5	[3],[4]	6		7
Defined Benefit Plan, Actual Return on Plan Assets Still Held		0		0		1
Defined Benefit Plan, Purchases, Sales, and Settlements		(1)		(1)		(2)
Ending balance		4	[3],[4]	5	[3],[4]	6
UK Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		2,368		2,177
Foreign Currency Exchange Rate Changes		(128)		(145)
Ending balance		2,276		2,368		2,177
UK Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	[5]	199
Ending balance	[5]	204		199
UK Pension Plans [Member] | Real Estate Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance		199
Ending balance		204		199
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		199	[5]	179		163
Defined Benefit Plan, Actual Return on Plan Assets Still Held		18		33		12
Foreign Currency Exchange Rate Changes		(13)		(13)		4
Ending balance		$ 204	[5]	$ 199	[5]	$ 179
[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]	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]	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, 2015	Dec. 31, 2014	Dec. 31, 2013	May. 31, 2015
Defined Contribution Plan, Cost Recognized	$ 90	$ 83	$ 63
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	(8)	$ (2)
Domestic Other Postretirement Plans [Member] | PacifiCorp [Member]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax				$ 9
Defined Benefit Plan, Amount To Be Transferred	$ 150

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, 2015	May. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	$ 8		$ 2
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	$ 9	$ 9	$ 2

Employee Benefit Plans - Pac228

Employee Benefit Plans - PacifiCorp - Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	$ 33	$ 36	$ 24
Defined Benefit Plan, Interest Cost	121	131	87
Defined Benefit Plan, Expected Return on Plan Assets	(169)	(164)	(119)
Defined Benefit Plan Net Amortization	53	44	58
Defined Benefit Plan, Net Periodic Benefit Cost	38	47	50
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	11	14	14
Defined Benefit Plan, Interest Cost	31	46	33
Defined Benefit Plan, Expected Return on Plan Assets	(45)	(53)	(44)
Defined Benefit Plan Net Amortization	(11)	(3)	6
Defined Benefit Plan, Net Periodic Benefit Cost	(14)	4	9
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	4	5	6
Defined Benefit Plan, Interest Cost	53	57	54
Defined Benefit Plan, Expected Return on Plan Assets	(77)	(76)	(74)
Defined Benefit Plan Net Amortization	42	29	48
Defined Benefit Plan, Net Periodic Benefit Cost	22	15	34
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	3	6	9
Defined Benefit Plan, Interest Cost	16	28	25
Defined Benefit Plan, Expected Return on Plan Assets	(23)	(31)	(30)
Defined Benefit Plan Net Amortization	(4)	2	8
Defined Benefit Plan, Net Periodic Benefit Cost	$ (8)	$ 5	$ 12

Employee Benefit Plans - Pac229

Employee Benefit Plans - PacifiCorp - Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2015	May. 31, 2015	Dec. 31, 2014
Domestic Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	$ 2,718	$ 2,711
Defined Benefit Plan, Contributions by Employer	13	37
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actual Return on Plan Assets	(17)	188
Defined Benefit Plan, Settlements, Plan Assets	23	0
Defined Benefit Plan, Benefits Paid	(202)	(218)
Ending balance	2,489	2,718	$ 2,711
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	3,119	2,821
Defined Benefit Plan, Service Cost	33	36	24
Defined Benefit Plan, Interest Cost	121	131	87
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actuarial Gain (Loss)	(110)	349
Defined Benefit Plan, Settlements, Benefit Obligation	(23)	0
Defined Benefit Plan, Benefits Paid	(202)	(218)
Defined Benefit Plan, Benefit Obligation	3,119	2,821	2,821	$ 2,934		$ 3,119
Defined Benefit Plan, Accumulated Benefit Obligation				2,906		3,086
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan				(445)		(401)
Other current liabilities				(15)		(14)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(437)		(399)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(445)		(401)
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	858	852
Defined Benefit Plan, Contributions by Employer	2	2
Defined Benefit Plan, Contributions by Plan Participants	9	11
Defined Benefit Plan, Actual Return on Plan Assets	0	54
Defined Benefit Plan, Settlements, Plan Assets	150	0
Defined Benefit Plan, Benefits Paid	(57)	(61)
Ending balance	662	858	852
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	936	987
Defined Benefit Plan, Service Cost	11	14	14
Defined Benefit Plan, Interest Cost	31	46	33
Defined Benefit Plan, Contributions by Plan Participants	9	11
Defined Benefit Plan, Actuarial Gain (Loss)	(43)	(61)
Defined Benefit Plan, Settlements, Benefit Obligation	(150)	0
Defined Benefit Plan, Benefits Paid	(57)	(61)
Defined Benefit Plan, Benefit Obligation	936	987	987	740		936
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan				(78)		(78)
Other current liabilities				0		0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(93)		(88)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(78)		(78)
Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount				228		247
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	1,146	1,171
Defined Benefit Plan, Contributions by Employer	4	10
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actual Return on Plan Assets	0	53
Defined Benefit Plan, Settlements, Plan Assets	0	0
Defined Benefit Plan, Benefits Paid	(107)	(88)
Ending balance	1,043	1,146	1,171
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	1,378	1,230
Defined Benefit Plan, Service Cost	4	5	6
Defined Benefit Plan, Interest Cost	53	57	54
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actuarial Gain (Loss)	(39)	174
Defined Benefit Plan, Settlements, Benefit Obligation	0	0
Defined Benefit Plan, Benefits Paid	(107)	(88)
Defined Benefit Plan, Benefit Obligation	1,378	1,230	1,230	1,289		1,378
Defined Benefit Plan, Accumulated Benefit Obligation				1,289		1,378
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan				(246)		(232)
Other current liabilities				(4)		(4)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(242)		(228)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(246)		(232)
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	482	486
Defined Benefit Plan, Contributions by Employer	1	1
Defined Benefit Plan, Contributions by Plan Participants	6	7
Defined Benefit Plan, Actual Return on Plan Assets	1	25
Defined Benefit Plan, Settlements, Plan Assets	150	0
Defined Benefit Plan, Benefits Paid	(35)	(37)
Ending balance	305	482	486
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	539	598
Defined Benefit Plan, Service Cost	3	6	9
Defined Benefit Plan, Interest Cost	16	28	25
Defined Benefit Plan, Contributions by Plan Participants	6	7
Defined Benefit Plan, Actuarial Gain (Loss)	(17)	(63)
Defined Benefit Plan, Settlements, Benefit Obligation	(150)	0
Defined Benefit Plan, Benefits Paid	(35)	(37)
Defined Benefit Plan, Benefit Obligation	$ 539	$ 598	$ 598	362		539
Defined Benefit Plan, Amount To Be Transferred				150	$ 150
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan				(57)		(57)
Other current liabilities				0		0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent				(57)		(57)
Defined Benefit Plan, Amounts Recognized in Balance Sheet				(57)		(57)
PacifiCorp [Member] | Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount				$ 52		$ 51

Employee Benefit Plans - Pac230

Employee Benefit Plans - PacifiCorp - Unrecognized Amounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	May. 31, 2015	Dec. 31, 2013
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	$ 61
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(27)
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	0
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	34
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	768	$ 757
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(25)	(31)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	(2)	(3)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	741	723		$ 441
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	75	326
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(53)	(44)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	18	282
Defined Benefit Plan, Amortization of Gains (Losses), Net	58
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(11)
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	46
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	97	108
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(68)	(87)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	8	2
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	37	23		83
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	(63)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	11	3
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	14	(60)
Defined Benefit Plan, Amortization of Gains (Losses), Net	3
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(16)
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	(12)
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		490
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	258
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(53)	(38)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	19	220
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	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		99
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)	(64)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	10	2
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	12	(62)
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	19		9
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)	16
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	0	(6)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(6)	10
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	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	43
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(15)
Defined Benefit Plan, Amortization of Regulatory Deferrals, Net	0
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	28
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	508	520
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(13)	(21)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	(3)	(3)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	492	496		328
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	38	197
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(42)	(29)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(4)	168
Defined Benefit Plan, Amortization of Gains (Losses), Net	42
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(8)
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	33
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	36	41
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(19)	(26)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Regulatory Deferrals, Before Tax	9	2	$ 9
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	26	17
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	1
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	(5)
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	473	474		313
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	40	189
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(41)	(28)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(1)	161
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	26	17		77
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	(58)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	4	(2)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	9	(60)
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	19	22		$ 15
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)	8
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	$ (3)	$ 7

Employee Benefit Plans - Pac231

Employee Benefit Plans - PacifiCorp - Plan Assumptions (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.70%	8.00%
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
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.43%	4.00%	4.81%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.75%	2.75%	3.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.00%	4.81%	4.03%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.88%	6.86%	7.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.75%	3.00%	3.00%
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.33%	3.88%	4.82%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.93%	4.82%	4.01%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.00%	7.34%	7.44%
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.40%	4.00%	4.80%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.75%	2.75%	3.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.00%	4.80%	4.05%
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%	3.00%	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	4.35%	3.90%	4.90%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.99%	4.90%	4.10%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.08%	7.50%	7.50%
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year		8.00%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate		5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate		2,025

Employee Benefit Plans - Pac232

Employee Benefit Plans - PacifiCorp - Contributions and Benefit Payments (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	$ 34
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	221
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	224
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	226
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	224
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	225
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	1,054
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	56
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	57
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	58
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	58
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	61
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	272
PacifiCorp [Member] | Domestic Pension 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	108
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	110
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	108
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	109
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	107
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	448
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	28
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	27
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	30
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	$ 122

Employee Benefit Plans - Pac233

Employee Benefit Plans - PacifiCorp - Asset Allocations (Details) - PacifiCorp [Member]	12 Months Ended
	Dec. 31, 2015	[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 - Pac234

Employee Benefit Plans - PacifiCorp - Fair Value Measurements (Details) - USD ($) $ in Millions		Dec. 31, 2015		May. 31, 2015	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 2,489			$ 2,718		$ 2,711
Domestic Pension Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	1,007			1,302
Domestic Pension Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	1,370			1,306
Domestic Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	112			110
Domestic Pension Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		31			69
Domestic 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	[1]	0			15
Domestic 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	[1]	31			54
Domestic 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	[1]	0			0
Domestic Pension Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		155			166
Domestic Pension 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]	155			166
Domestic Pension 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 Pension 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 Pension Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		335			268
Domestic 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	[1]	0			0
Domestic 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	[1]	335			268
Domestic 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	[1]	0			0
Domestic Pension Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		25			27
Domestic Pension 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 Pension 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]	25			27
Domestic Pension 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 Pension Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		154			94
Domestic Pension 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 Pension 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]	154			94
Domestic Pension 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 Pension Plans [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		586			698
Domestic Pension 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]	586			698
Domestic Pension 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 Pension 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 Pension Plans [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		122			122
Domestic Pension 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]	122			122
Domestic Pension 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 Pension 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 Pension Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	$ 965			$ 1,153
Percentage of Investment Funds Comprised Of Equity Securitites		66.00%			61.00%
Percentage of Investment Funds Comprised Of Debt Securities		34.00%			39.00%
Percentage Of Investment Funds Invested in United States Securities		58.00%			64.00%
Percentage Of Investment Funds Invested In International Securities		42.00%			36.00%
Domestic 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	[1],[2]	$ 144			$ 301
Domestic 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	[1],[2]	821			852
Domestic 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	[1],[2]	0			0
Domestic Pension Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	65			70
Domestic Pension Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1],[3]	0			0
Domestic Pension Plans [Member] | Limited Partnership Interests [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 Pension Plans [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		65	[1],[3]		70	[1],[3]	86	$ 96
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		662			858		852
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	[4]	401			613
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	[4]	257			240
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	[4]	4			5
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		14	[5]		146
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]	12	[5]		145
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	[4]	2	[5]		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	[4]	0	[5]		0
Domestic Other Postretirement Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		18			17
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	[4]	18			17
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	[4]	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	[4]	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		33			34
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	[4]	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	[4]	33			34
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	[4]	0			0
Domestic Other Postretirement Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		41			43
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	[4]	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	[4]	41			43
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	[4]	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		28			31
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	[4]	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	[4]	28			31
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	[4]	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		216			243
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	[4]	216			243
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	[4]	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	[4]	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		6			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	[4]	6			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	[4]	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	[4]	0			0
Domestic Other Postretirement Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[6]	$ 302			$ 333
Percentage of Investment Funds Comprised Of Equity Securitites		63.00%			63.00%
Percentage of Investment Funds Comprised Of Debt Securities		37.00%			37.00%
Percentage Of Investment Funds Invested in United States Securities		70.00%			69.00%
Percentage Of Investment Funds Invested In International Securities		30.00%			31.00%
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	[4],[6]	$ 149			$ 202
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	[4],[6]	153			131
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	[4],[6]	0			0
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[7]	4			5
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4],[7]	0			0
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[4],[7]	0			0
Domestic Other Postretirement Plans [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		4	[4],[7]		5	[4],[7]	6	7
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,043			1,146		1,171
PacifiCorp [Member] | Domestic Pension Plans [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		527			736
PacifiCorp [Member] | Domestic Pension Plans [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		451			340
PacifiCorp [Member] | Domestic Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		65			70
PacifiCorp [Member] | Domestic Pension Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		10			8
PacifiCorp [Member] | Domestic 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		0			0
PacifiCorp [Member] | Domestic 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		10			8
PacifiCorp [Member] | Domestic 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		0			0
PacifiCorp [Member] | Domestic Pension Plans [Member] | US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		19			15
PacifiCorp [Member] | Domestic Pension 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		19			15
PacifiCorp [Member] | Domestic Pension 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 Pension 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 Pension Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		42			53
PacifiCorp [Member] | Domestic 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		0			0
PacifiCorp [Member] | Domestic 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		42			53
PacifiCorp [Member] | Domestic 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		0			0
PacifiCorp [Member] | Domestic Pension Plans [Member] | Municipal Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5			8
PacifiCorp [Member] | Domestic Pension 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 Pension 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		5			8
PacifiCorp [Member] | Domestic Pension 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 Pension Plans [Member] | US Government-sponsored Enterprises Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		43			48
PacifiCorp [Member] | Domestic Pension 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 Pension 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		43			48
PacifiCorp [Member] | Domestic Pension 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 Pension Plans [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		408			488
PacifiCorp [Member] | Domestic Pension 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		408			488
PacifiCorp [Member] | Domestic Pension 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 Pension 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 Pension Plans [Member] | Foreign Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		17			16
PacifiCorp [Member] | Domestic Pension 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		17			16
PacifiCorp [Member] | Domestic Pension 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 Pension 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 Pension Plans [Member] | Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 434			$ 440
Percentage of Investment Funds Comprised Of Equity Securitites		53.00%			50.00%
Percentage of Investment Funds Comprised Of Debt Securities		47.00%			50.00%
Percentage Of Investment Funds Invested in United States Securities		40.00%			43.00%
Percentage Of Investment Funds Invested In International Securities		60.00%			57.00%
PacifiCorp [Member] | Domestic 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		$ 83			$ 217
PacifiCorp [Member] | Domestic 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		351			223
PacifiCorp [Member] | Domestic 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		0			0
PacifiCorp [Member] | Domestic Pension Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		65			70
PacifiCorp [Member] | Domestic Pension Plans [Member] | Limited Partnership Interests [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 Pension Plans [Member] | Limited Partnership Interests [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 Pension Plans [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		65			70		86	96
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		305			482		486
Defined Benefit Plan, Amount To Be Transferred		150		$ 150
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			347
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		157			130
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		4			5
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			139
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			139
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			0
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		9			8
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		9			8
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		15			18
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		15			18
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		1			2
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		1			2
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		14			16
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		14			16
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		95			112
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		95			112
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		$ 158			$ 178
Percentage of Investment Funds Comprised Of Equity Securitites		61.00%			63.00%
Percentage of Investment Funds Comprised Of Debt Securities		39.00%			37.00%
Percentage Of Investment Funds Invested in United States Securities		67.00%			64.00%
Percentage Of Investment Funds Invested In International Securities		33.00%			36.00%
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			$ 84
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		126			94
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
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		4			5
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [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] | Limited Partnership Interests [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] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 4			$ 5		$ 6	$ 7
[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 66% and 34%, respectively, for 2015 and 61% and 39%, respectively, for 2014. Additionally, these funds are invested in United States and international securities of approximately 58% and 42%, respectively, for 2015 and 64% and 36%, respectively, for 2014.
[3]	Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
[4]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[5]	In December 2014, PacifiCorp began to migrate funds to cash and cash equivalents in anticipation of the $150 million to be transferred to a fund managed by the UMWA in May 2015 as a result of the other postretirement settlement. Remaining investments were rebalanced to align to PacifiCorp's target investment allocations.
[6]	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 2015 and 63% and 37%, respectively, for 2014. Additionally, these funds are invested in United States and international securities of approximately 70% and 30%, respectively, for 2015 and 69% and 31%, respectively, for 2014.
[7]	Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.

Employee Benefit Plans - Pac235

Employee Benefit Plans - PacifiCorp - Level 3 Rollforward (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		$ 2,718		$ 2,711
Ending balance		2,489		2,718		$ 2,711
Domestic Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	[1]	110
Ending balance	[1]	112		110
Domestic Pension Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	[2]	70
Ending balance	[2]	65		70
Domestic Pension Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		70	[1],[2]	86		96
Defined Benefit Plan, Actual Return on Plan Assets Still Held		5		(1)		16
Defined Benefit Plan, Purchases, Sales, and Settlements		(10)		(15)		(26)
Ending balance		65	[1],[2]	70	[1],[2]	86
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		858		852
Ending balance		662		858		852
Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	[3]	5
Ending balance	[3]	4		5
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	[4]	5
Ending balance	[4]	4		5
Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		5	[3],[4]	6		7
Defined Benefit Plan, Actual Return on Plan Assets Still Held		0		0		1
Defined Benefit Plan, Purchases, Sales, and Settlements		(1)		(1)		(2)
Ending balance		4	[3],[4]	5	[3],[4]	6
PacifiCorp [Member] | Domestic Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		1,146		1,171
Ending balance		1,043		1,146		1,171
PacifiCorp [Member] | Domestic Pension Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		70
Ending balance		65		70
PacifiCorp [Member] | Domestic Pension Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		70
Ending balance		65		70
PacifiCorp [Member] | Domestic Pension Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		70		86		96
Defined Benefit Plan, Actual Return on Plan Assets Still Held		5		(1)		16
Defined Benefit Plan, Purchases, Sales, and Settlements		(10)		(15)		(26)
Ending balance		65		70		86
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		482		486
Ending balance		305		482		486
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		5
Ending balance		4		5
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		5
Ending balance		4		5
PacifiCorp [Member] | Domestic Other Postretirement Plans [Member] | Limited Partnership Interests [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance		5		6		7
Defined Benefit Plan, Actual Return on Plan Assets Still Held		0		0		1
Defined Benefit Plan, Purchases, Sales, and Settlements		(1)		(1)		(2)
Ending balance		$ 4		$ 5		$ 6
[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]	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.

Employee Benefit Plans - Pac236

Employee Benefit Plans - PacifiCorp - Multiemployer and Joint Trust Pension Plans (Details) - PacifiCorp [Member] - USD ($) $ in Millions		12 Months Ended
		Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Joint Trustee Plan, Percentage By Which Joint Trustee Plan was at Least Funded				80.00%		80.00%
Joint Trustee Plan, Period Contributions	[1]		$ 8		$ 9		$ 9
UMWA Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Multiemployer Plans, Withdrawal Obligation, Most Recent Estimate			97
Multiemployer Plans, Certified Zone Status				Red		Orange
Multiemployer Plan, Period Contributions	[1]		$ 1		$ 2		$ 3
Subsequent Event [Member]
Defined Benefit Plan Disclosure [Line Items]
Joint Trustee Plan, Percentage By Which Joint Trustee Plan was at Least Funded		80.00%
Subsequent Event [Member] | UMWA Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Multiemployer Plans, Certified Zone Status		Red
[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, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	$ 90	$ 83	$ 63
PacifiCorp [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	$ 35	$ 34	$ 35

Employee Benefit Plans - MEC -

Employee Benefit Plans - MEC - Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	$ 33	$ 36	$ 24
Defined Benefit Plan, Interest Cost	121	131	87
Defined Benefit Plan, Expected Return on Plan Assets	(169)	(164)	(119)
Defined Benefit Plan Net Amortization	53	44	58
Defined Benefit Plan, Net Periodic Benefit Cost	38	47	50
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	11	14	14
Defined Benefit Plan, Interest Cost	31	46	33
Defined Benefit Plan, Expected Return on Plan Assets	(45)	(53)	(44)
Defined Benefit Plan Net Amortization	(11)	(3)	6
Defined Benefit Plan, Net Periodic Benefit Cost	(14)	4	9
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	12	14	18
Defined Benefit Plan, Interest Cost	32	35	33
Defined Benefit Plan, Expected Return on Plan Assets	(46)	(45)	(45)
Defined Benefit Plan Net Amortization	2	1	11
Defined Benefit Plan, Net Periodic Benefit Cost	0	5	17
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	7	6	5
Defined Benefit Plan, Interest Cost	9	10	8
Defined Benefit Plan, Expected Return on Plan Assets	(15)	(15)	(13)
Defined Benefit Plan Net Amortization	(3)	(3)	(3)
Defined Benefit Plan, Net Periodic Benefit Cost	(2)	(2)	(3)
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	(4)	1	11
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	$ 0	$ 0	$ (1)

Employee Benefit Plans - MEC239

Employee Benefit Plans - MEC - Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
United States Pension Plan of US Entity [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	$ 2,718	$ 2,711
Defined Benefit Plan, Contributions by Employer	13	37
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actual Return on Plan Assets	(17)	188
Defined Benefit Plan, Benefits Paid	(202)	(218)
Ending balance	2,489	2,718	$ 2,711
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	3,119	2,821
Defined Benefit Plan, Service Cost	33	36	24
Defined Benefit Plan, Interest Cost	121	131	87
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actuarial Gain (Loss)	(110)	349
Defined Benefit Plan, Benefits Paid	(202)	(218)
Ending balance	2,934	3,119	2,821
Defined Benefit Plan, Accumulated Benefit Obligation	2,906	3,086
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan	(445)	(401)
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	7	12
Other current liabilities	(15)	(14)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(437)	(399)
Defined Benefit Plan, Amounts Recognized in Balance Sheet	(445)	(401)
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	858	852
Defined Benefit Plan, Contributions by Employer	2	2
Defined Benefit Plan, Contributions by Plan Participants	9	11
Defined Benefit Plan, Actual Return on Plan Assets	0	54
Defined Benefit Plan, Benefits Paid	(57)	(61)
Ending balance	662	858	852
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	936	987
Defined Benefit Plan, Service Cost	11	14	14
Defined Benefit Plan, Interest Cost	31	46	33
Defined Benefit Plan, Contributions by Plan Participants	9	11
Defined Benefit Plan, Actuarial Gain (Loss)	(43)	(61)
Defined Benefit Plan, Benefits Paid	(57)	(61)
Ending balance	740	936	987
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan	(78)	(78)
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	15	10
Other current liabilities	0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(93)	(88)
Defined Benefit Plan, Amounts Recognized in Balance Sheet	(78)	(78)
Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount	228	247
MidAmerican Energy Company [Member]
Defined Benefit Plans, Supplemental Employee Retirement Plans [Abstract]
Life Insurance, Corporate or Bank Owned, Amount	175	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	730	722
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	4	52
Defined Benefit Plan, Benefits Paid	(63)	(51)
Ending balance	678	730	722
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	840	768
Defined Benefit Plan, Service Cost	12	14	18
Defined Benefit Plan, Interest Cost	32	35	33
Defined Benefit Plan, Contributions by Plan Participants	0	0
Defined Benefit Plan, Actuarial Gain (Loss)	(36)	74
Defined Benefit Plan, Benefits Paid	(63)	(51)
Ending balance	785	840	768
Defined Benefit Plan, Accumulated Benefit Obligation	773	825
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan	(107)	(110)
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	7	12
Other current liabilities	(8)	(8)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(106)	(114)
Defined Benefit Plan, Amounts Recognized in Balance Sheet	(107)	(110)
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Beginning balance	259	256
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	0	13
Defined Benefit Plan, Benefits Paid	(12)	(12)
Ending balance	249	259	256
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Beginning balance	249	235
Defined Benefit Plan, Service Cost	7	6	5
Defined Benefit Plan, Interest Cost	9	10	8
Defined Benefit Plan, Contributions by Plan Participants	1	1
Defined Benefit Plan, Actuarial Gain (Loss)	(20)	9
Defined Benefit Plan, Benefits Paid	(12)	(12)
Ending balance	234	249	$ 235
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan	15	10
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	15	10
Other current liabilities	0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	0	0
Defined Benefit Plan, Amounts Recognized in Balance Sheet	15	10
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	156	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	$ 104	$ 103

Employee Benefit Plans - MEC240

Employee Benefit Plans - MEC - Unrecognized Amounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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	$ 61
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(27)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	34
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	768	$ 757
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(25)	(31)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	741	723	$ 441
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	75	326
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(53)	(44)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	18	282
Defined Benefit Plan, Amortization of Gains (Losses), Net	58
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(11)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	46
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	97	108
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(68)	(87)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	37	23	83
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	(63)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	11	3
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	14	(60)
Defined Benefit Plan, Amortization of Gains (Losses), Net	3
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(16)
Defined Benefit Plan, Amounts That Will Be Amortized from Regulatory Assets (Liabilities) and Accumulated Other Comprehensive Income Loss In Next Fiscal Year	(12)
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	26	21
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	2	3
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	28	24	(41)
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	66
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(2)	(1)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	4	65
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	42	49
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Net Prior Service Cost (Credit), Before Tax	(36)	(42)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Before Tax	6	7	(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	(5)	10
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	4	3
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	(1)	13
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)
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	729	710	490
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	258
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(53)	(38)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	19	220
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	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	99
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)	(64)
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	10	2
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	12	(62)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	(3)
Regulatory Asset, Pension and Other Postretirement Costs [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 Not Yet Recognized, Before Tax	22	22	16
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	6
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	(2)	0
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	0	6
Regulatory Asset, Pension and Other Postretirement Costs [Member] | 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, Before Tax	17	20	10
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)	8
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	(3)	10
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	(1)	(6)	(58)
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	52
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	5	52
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	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)	(16)
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	2	2
Defined Benefit Plan, Amortization of Prior Service Cost (Credit), Net	0
Regulatory Liability, Pension and Other Postretirement Costs [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 Not Yet Recognized, Before Tax	0	(5)	(55)
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	51
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	0	(1)
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	5	50
Regulatory Liability, Pension and Other Postretirement Costs [Member] | 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, 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
Receivables (Payables) With Affiliates [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 Not Yet Recognized, Before Tax	6	7	(2)
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)	9
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	(1)	9
Receivables (Payables) With Affiliates [Member] | 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, Before Tax	(11)	(13)	$ (16)
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	2
Defined Benefit Plan, Net Amortization Recognized in Net Periodic Benefit Cost Before Tax	2	1
Defined Benefit Plan, Net Periodic Benefit Cost Not Yet Recognized, Arising During Period, Before Tax	$ 2	$ 3

Employee Benefit Plans - MEC241

Employee Benefit Plans - MEC - Plan Assumptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.70%	8.00%
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	(1)
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	5
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	$ (5)
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.43%	4.00%	4.81%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.75%	2.75%	3.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.00%	4.81%	4.03%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.88%	6.86%	7.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.75%	3.00%	3.00%
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.33%	3.88%	4.82%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.93%	4.82%	4.01%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.00%	7.34%	7.44%
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	5.18%	5.37%	5.56%
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	4.50%	4.00%	4.75%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	2.75%	2.75%	3.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.00%	4.75%	4.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.25%	7.50%	7.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	2.75%	3.00%	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	4.25%	3.75%	4.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.75%	4.50%	3.75%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.00%	7.25%	7.25%
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.70%	8.00%
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	3
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	$ (3)

Employee Benefit Plans - MEC242

Employee Benefit Plans - MEC - Contributions and Benefit Payments (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
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	$ 34
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	221
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	224
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	226
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	224
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	225
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	1,054
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	56
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	57
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	58
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	58
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	61
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	272
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	59
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	60
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	60
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	60
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	61
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	291
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	17
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	$ 102

Employee Benefit Plans - MEC243

Employee Benefit Plans - MEC - Asset Allocations (Details) - MidAmerican Energy Company [Member]	12 Months Ended
	Dec. 31, 2015
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%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	40.00%
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%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	80.00%
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%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	45.00%
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%
Defined Benefit Plan, Target Plan Asset Allocations Range Maximum	80.00%
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%

Employee Benefit Plans - MEC244

Employee Benefit Plans - MEC - Fair Value Measurements (Details) - USD ($) $ in Millions		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 2,489		$ 2,718		$ 2,711
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]	1,007		1,302
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]	1,370		1,306
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]	112		110
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		31		69
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]	0		15
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]	31		54
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		155		166
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]	155		166
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		335		268
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]	335		268
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		25		27
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]	25		27
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		154		94
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]	154		94
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		586		698
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]	586		698
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		122		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]	122		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]	$ 965		$ 1,153
Percentage of Investment Funds Comprised Of Equity Securitites		66.00%		61.00%
Percentage of Investment Funds Comprised Of Debt Securities		34.00%		39.00%
Percentage Of Investment Funds Invested in United States Securities		58.00%		64.00%
Percentage Of Investment Funds Invested In International Securities		42.00%		36.00%
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]	$ 144		$ 301
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]	821		852
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] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		47		40
United States Pension Plan of US Entity [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	[1]	0		0
United States Pension Plan of US Entity [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	[1]	0		0
United States Pension Plan of US Entity [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		47	[1]	40	[1]	31	$ 26
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		662		858		852
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]	401		613
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]	257		240
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]	4		5
Domestic Other Postretirement Plans [Member] | Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		14	[4]	146
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]	12	[4]	145
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		18		17
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]	18		17
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		33		34
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]	33		34
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		41		43
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]	41		43
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		28		31
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]	28		31
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		216		243
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]	216		243
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		6		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]	6		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]	$ 302		$ 333
Percentage of Investment Funds Comprised Of Equity Securitites		63.00%		63.00%
Percentage of Investment Funds Comprised Of Debt Securities		37.00%		37.00%
Percentage Of Investment Funds Invested in United States Securities		70.00%		69.00%
Percentage Of Investment Funds Invested In International Securities		30.00%		31.00%
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]	$ 149		$ 202
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]	153		131
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
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		678		730		722
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		236		281
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		395		409
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		47		40
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		16		24
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		16		24
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		5		8
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		5		8
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		57		29
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		57		29
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		4
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		4
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		27		33
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		27		33
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		149
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		149
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		40		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		40		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		$ 350		$ 403
Percentage of Investment Funds Comprised Of Equity Securitites		72.00%		68.00%
Percentage of Investment Funds Comprised Of Debt Securities		28.00%		32.00%
Percentage Of Investment Funds Invested in United States Securities		73.00%		74.00%
Percentage Of Investment Funds Invested In International Securities		27.00%		26.00%
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		$ 61		$ 84
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		289		319
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] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		47		40
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [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		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [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		0		0
MidAmerican Energy Company [Member] | United States Pension Plan of US Entity [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		47		40		31	$ 26
MidAmerican Energy Company [Member] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		249		259		$ 256
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		186		193
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		63		66
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		5		4
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		5		4
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		12		11
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		12		11
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		39		40
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		39		40
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		12		15
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		12		15
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		120		128
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		120		128
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		$ 56		$ 56
Percentage of Investment Funds Comprised Of Equity Securitites		68.00%		69.00%
Percentage of Investment Funds Comprised Of Debt Securities		32.00%		31.00%
Percentage Of Investment Funds Invested in United States Securities		32.00%		31.00%
Percentage Of Investment Funds Invested In International Securities		68.00%		69.00%
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		$ 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		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		$ 0		$ 0
[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 66% and 34%, respectively, for 2015 and 61% and 39%, respectively, for 2014. Additionally, these funds are invested in United States and international securities of approximately 58% and 42%, respectively, for 2015 and 64% and 36%, respectively, for 2014.
[3]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.
[4]	In December 2014, PacifiCorp began to migrate funds to cash and cash equivalents in anticipation of the $150 million to be transferred to a fund managed by the UMWA in May 2015 as a result of the other postretirement settlement. Remaining investments were rebalanced to align to PacifiCorp's target investment allocations.
[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 2015 and 63% and 37%, respectively, for 2014. Additionally, these funds are invested in United States and international securities of approximately 70% and 30%, respectively, for 2015 and 69% and 31%, respectively, for 2014.

Employee Benefit Plans - MEC245

Employee Benefit Plans - MEC - Level 3 Rollforward (Details) - United States Pension Plan of US Entity [Member] - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 2,489		$ 2,718		$ 2,711
Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	112		110
Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		47		40
Real Estate Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		47	[1]	40	[1]	31	$ 26
Defined Benefit Plan, Actual Return on Plan Assets Still Held		7		4		5
Defined Benefit Plan, Purchases, Sales, and Settlements		0		5		0
MidAmerican Energy Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		678		730		722
MidAmerican Energy Company [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		47		40
MidAmerican Energy Company [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		47		40
MidAmerican Energy Company [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		47		40		31	$ 26
Defined Benefit Plan, Actual Return on Plan Assets Still Held		7		4		5
Defined Benefit Plan, Purchases, Sales, and Settlements		$ 0		$ 5		$ 0
[1]	Refer to Note 15 for additional discussion regarding the three levels of the fair value hierarchy.

Employee Benefit Plans - MEC246

Employee Benefit Plans - MEC - Defined Contribution Plans (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	$ 90	$ 83	$ 63
MidAmerican Energy Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	$ 20	$ 19	$ 17

Employee Benefit Plans - MidAme

Employee Benefit Plans - MidAmerican Funding - Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
United States Pension Plan of US Entity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	$ 38	$ 47	$ 50
Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	(14)	4	9
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	6
MidAmerican Funding, LLC and Subsidiaries [Domain] | Domestic Other Postretirement Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	$ (2)	$ (2)	$ (2)

Retirement Plan and Postreti248

Retirement Plan and Postretirement Benefits - NPC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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	$ 437	$ 399
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	15	14
Defined Benefit Plan, Contributions by Employer	13	37
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	0	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	38	23
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	5	1
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 Postreti249

Retirement Plan and Postretirement Benefits - SPPC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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	$ 13	$ 37
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	(437)	(399)
Other current liabilities	(15)	(14)
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	0	0	$ 20
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	0	0	$ 5
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	(29)	(13)
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)	(10)
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	(32)	(33)
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, 2015	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		$ 921	$ 753	$ 696
Regulatory Liabilities		3,033	2,832
Fossil Fuel Plant [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		443	334
Quad Cities Station [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		289	265
Wind Generating Facility [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		104	75
Offshore pipeline facilities [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		31	31
Solar Generating Facility [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		12	9
Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		42	39
Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[1]	2,167	2,215
Quad Cities Station nuclear decommissioning trust funds [Member]
Asset Retirement Obligations By Type [Line Items]
Nuclear decommissioning trust funds		$ 429	$ 424
[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 Obligations251

Asset Retirement Obligations - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 753	$ 696
Acquisitions	0	12
Asset Retirement Obligation, Revision of Estimate	104	3
Asset Retirement Obligation, Liabilities Incurred	59	15
Retirements	(32)	(8)
Asset Retirement Obligation, Accretion Expense	37	35
Asset Retirement Obligation	753	696	$ 921	$ 753
Asset Retirement Obligation, Current			92	66
Asset Retirement Obligations, Noncurrent			$ 829	$ 687
Ending Balance	$ 921	$ 753

Asset Retirement Obligations252

Asset Retirement Obligations - PacifiCorp - Asset Retirement Obligations By Type (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations By Type [Line Items]
Regulatory liabilities	$ 2,631	$ 2,669
PacifiCorp [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory liabilities	938	910
PacifiCorp [Member] | Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory liabilities	$ 894	$ 873

Asset Retirement Obligations253

Asset Retirement Obligations - PacifiCorp - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 753	$ 696
Asset Retirement Obligation, Revision of Estimate	104	3
Asset Retirement Obligation, Liabilities Incurred	59	15
Retirements	(32)	(8)
Asset Retirement Obligation, Accretion Expense	37	35
Asset Retirement Obligation	753	696	$ 921	$ 753
Asset Retirement Obligation, Current			92	66
Asset Retirement Obligations, Noncurrent			829	687
Ending Balance	921	753
PacifiCorp [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	135	138
Asset Retirement Obligation, Revision of Estimate	62	(3)
Asset Retirement Obligation, Liabilities Incurred	30	0
Retirements	(10)	(6)
Asset Retirement Obligation, Accretion Expense	7	6
Asset Retirement Obligation	135	138	224	135
Asset Retirement Obligation, Current			35	21
Asset Retirement Obligations, Noncurrent			$ 189	$ 114
Ending Balance	$ 224	$ 135

Asset Retirement Obligations254

Asset Retirement Obligations - MEC - Asset Retirement Obligations By Type (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		$ 921	$ 753	$ 696
Regulatory Liabilities		3,033	2,832
Quad Cities Unit Nos 1 and 2 [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		289	265
Fossil Fuel Plant [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		443	334
Wind Generating Facility [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		104	75
Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		42	39
MidAmerican Energy Company [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		532	460	$ 430
Decommissioning Fund Investments, Fair Value		429	424
MidAmerican Energy Company [Member] | Quad Cities Unit Nos 1 and 2 [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		289	265
MidAmerican Energy Company [Member] | Fossil Fuel Plant [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		160	132
MidAmerican Energy Company [Member] | Wind Generating Facility [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		82	60
MidAmerican Energy Company [Member] | Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		1	3
Quad Cities Unit Nos 1 and 2 [Member] | MidAmerican Energy Company [Member]
Asset Retirement Obligations By Type [Line Items]
Decommissioning Fund Investments, Fair Value		429	424
Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[1]	2,167	2,215
Removal Costs [Member] | MidAmerican Energy Company [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities		$ 653	$ 642
[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 Obligations255

Asset Retirement Obligations - MEC - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 753	$ 696
Asset Retirement Obligation, Revision of Estimate	104	3
Asset Retirement Obligation, Liabilities Incurred	59	15
Asset Retirement Obligation, Liabilities Settled	32	8
Asset Retirement Obligation, Accretion Expense	37	35
Asset Retirement Obligation, Current	92	66
Asset Retirement Obligations, Noncurrent	829	687
Ending Balance	921	753
MidAmerican Energy Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	460	430
Asset Retirement Obligation, Revision of Estimate	36	(2)
Asset Retirement Obligation, Liabilities Incurred	22	11
Asset Retirement Obligation, Liabilities Settled	9	0
Asset Retirement Obligation, Accretion Expense	23	21
Asset Retirement Obligation, Current	44	28
Asset Retirement Obligations, Noncurrent	488	432
Ending Balance	$ 532	$ 460

Asset Retirement Obligations256

Asset Retirement Obligations - NPC - Asset Retirement Obligation by Type (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities		$ 3,033	$ 2,832
Asset Retirement Obligation		921	753	$ 696
Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		42	39
Nevada Power Company [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities		477	366
Asset Retirement Obligation		85	86	$ 100
Nevada Power Company [Member] | Waste water remediation [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		42	53
Nevada Power Company [Member] | Evaporative Ponds and Dry Ash Landfills [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		27	25
Nevada Power Company [Member] | Asbestos [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		3	3
Nevada Power Company [Member] | Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		13	5
Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[1]	2,167	2,215
Removal Costs [Member] | Nevada Power Company [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[2]	$ 273	$ 295
[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, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 753	$ 696
Asset Retirement Obligation, Revision of Estimate	104	3
Asset Retirement Obligation, Liabilities Incurred	59	15
Retirements	(32)	(8)
Asset Retirement Obligation, Accretion Expense	37	35
Ending Balance	921	753
Asset Retirement Obligation, Current	92	66
Asset Retirement Obligations, Noncurrent	829	687
Nevada Power Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	86	100
Asset Retirement Obligation, Revision of Estimate	3	(18)
Asset Retirement Obligation, Liabilities Incurred	3	0
Retirements	(11)	0
Asset Retirement Obligation, Accretion Expense	4	4
Ending Balance	85	86
Asset Retirement Obligation, Current	13	14
Asset Retirement Obligations, Noncurrent	$ 72	$ 72

Asset Retirement Obligations258

Asset Retirement Obligations - SPPC - Asset Retirement Obligation by Type (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities		$ 3,033	$ 2,832
Asset Retirement Obligation		921	753	$ 696
Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		42	39
Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[1]	2,167	2,215
Sierra Pacific Power Company [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities		308	301
Asset Retirement Obligation		10	11	$ 16
Sierra Pacific Power Company [Member] | Asbestos [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		4	5
Sierra Pacific Power Company [Member] | Evaporative Ponds and Dry Ash Landfills [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		3	2
Sierra Pacific Power Company [Member] | Other Plant in Service [Member]
Asset Retirement Obligations By Type [Line Items]
Asset Retirement Obligation		3	4
Sierra Pacific Power Company [Member] | Removal Costs [Member]
Asset Retirement Obligations By Type [Line Items]
Regulatory Liabilities	[2]	$ 208	$ 233
[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 Obligations259

Asset Retirement Obligations - SPPC - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 753	$ 696
Asset Retirement Obligation, Revision of Estimate	104	3
Retirements	(32)	(8)
Asset Retirement Obligation, Accretion Expense	37	35
Ending Balance	921	753
Asset Retirement Obligation, Current	92	66
Asset Retirement Obligations, Noncurrent	829	687
Sierra Pacific Power Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	11	16
Asset Retirement Obligation, Revision of Estimate	0	(6)
Retirements	(1)	0
Asset Retirement Obligation, Accretion Expense	0	1
Ending Balance	10	11
Asset Retirement Obligation, Current	0	3
Asset Retirement Obligations, Noncurrent	$ 10	$ 8

Commitments and Contingencies -

Commitments and Contingencies - Legal (Details) - PacifiCorp [Member] - USA Power [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Loss Contingencies [Line Items]
Loss Contingency, Damages and Attorney Fees Awarded, Value	$ 115
Loss Contingency, Damages Awarded, Value	113
Loss Contingency Accrual	122
Amount Awarded for Actual Damages [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Awarded by Jury, Value	18
Amount Awarded for Unjust Enrichment [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Awarded by Jury, Value	$ 113

Commitments and Contingencie261

Commitments and Contingencies - Commitments Table (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)number_of_projects	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Contractual Obligation [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 143
Operating Leases, Future Minimum Payments, Due in Two Years	118
Operating Leases, Future Minimum Payments, Due in Three Years	95
Operating Leases, Future Minimum Payments, Due in Four Years	77
Operating Leases, Future Minimum Payments, Due in Five Years	66
Operating Leases, Future Minimum Payments, Due Thereafter	1,007
Operating Leases, Future Minimum Payments Due	1,506
Contractual Obligation, Due in Next Twelve Months	4,082
Contractual Obligation, Due in Second Year	2,167
Contractual Obligation, Due in Third Year	1,631
Contractual Obligation, Due in Fourth Year	1,497
Contractual Obligation, Due in Fifth Year	1,354
Contractual Obligation, Due after Fifth Year	11,311
Contractual Obligation	22,042
Operating Leases, Rent Expense	161	$ 146	$ 118
MidAmerican Funding [Member]
Contractual Obligation [Line Items]
Coal transportation costs, railroad	$ 185	$ 159	$ 174
Number of Construction Projects | number_of_projects	4
Fuel, capacity and transmission contract commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	$ 2,214
Purchase Obligation, Due in Second Year	1,760
Purchase Obligation, Due in Third Year	1,345
Purchase Obligation, Due in Fourth Year	1,229
Purchase Obligation, Due in Fifth Year	1,129
Purchase Obligation, Due after Fifth Year	9,494
Purchase Obligation	17,171
Capital Addition Purchase Commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	1,544
Purchase Obligation, Due in Second Year	25
Purchase Obligation, Due in Third Year	11
Purchase Obligation, Due in Fourth Year	3
Purchase Obligation, Due in Fifth Year	3
Purchase Obligation, Due after Fifth Year	5
Purchase Obligation	1,591
Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	181
Purchase Obligation, Due in Second Year	264
Purchase Obligation, Due in Third Year	180
Purchase Obligation, Due in Fourth Year	188
Purchase Obligation, Due in Fifth Year	156
Purchase Obligation, Due after Fifth Year	805
Purchase Obligation	$ 1,774

Commitments and Contingencies _

Commitments and Contingencies – Hydroelectric (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Hydroelectric [Line Items]
Assets	$ 83,618	$ 81,816	$ 69,591
PacifiCorp [Member]
Hydroelectric [Line Items]
Assets	23,550	$ 23,404	$ 22,781
Capital expenditures required by hydroelectric licenses	252
PacifiCorp [Member] | Klamath Hydroelectric System [Member]
Hydroelectric [Line Items]
Dam removal cost limit	200
Assets	81
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

Commitments and Contingencie263

Commitments and Contingencies - PacifiCorp - Legal (Details) - PacifiCorp [Member] - USA Power [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Loss Contingencies [Line Items]
Loss Contingency, Damages and Attorney Fees Awarded, Value	$ 115
Loss Contingency, Damages Awarded, Value	113
Loss Contingency Accrual	122
Amount Awarded for Actual Damages [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Awarded by Jury, Value	18
Amount Awarded for Unjust Enrichment [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Awarded by Jury, Value	$ 113

Commitments and Contingencie264

Commitments and Contingencies - PacifiCorp - Hydroelectric (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Hydroelectric [Line Items]
Assets	$ 83,618	$ 81,816	$ 69,591
PacifiCorp [Member]
Hydroelectric [Line Items]
Assets	22,367	$ 22,205
Capital expenditures required by hydroelectric licenses	252
PacifiCorp [Member] | Klamath Hydroelectric System [Member]
Hydroelectric [Line Items]
Dam removal cost limit	200
Assets	81
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

Commitments and Contingencie265

Commitments and Contingencies - PacifiCorp - Commitments Tables (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Contractual Obligation [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 143
Operating Leases, Future Minimum Payments, Due in Two Years	118
Operating Leases, Future Minimum Payments, Due in Three Years	95
Operating Leases, Future Minimum Payments, Due in Four Years	77
Operating Leases, Future Minimum Payments, Due in Five Years	66
Operating Leases, Future Minimum Payments, Due Thereafter	1,007
Operating Leases, Future Minimum Payments Due	1,506
Contractual Obligation, Due in Next Twelve Months	4,082
Contractual Obligation, Due in Second Year	2,167
Contractual Obligation, Due in Third Year	1,631
Contractual Obligation, Due in Fourth Year	1,497
Contractual Obligation, Due in Fifth Year	1,354
Contractual Obligation, Due after Fifth Year	11,311
Contractual Obligation	22,042
Capital Addition Purchase Commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	1,544
Purchase Obligation, Due in Second Year	25
Purchase Obligation, Due in Third Year	11
Purchase Obligation, Due in Fourth Year	3
Purchase Obligation, Due in Fifth Year	3
Purchase Obligation, Due after Fifth Year	5
Purchase Obligation	1,591
Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	181
Purchase Obligation, Due in Second Year	264
Purchase Obligation, Due in Third Year	180
Purchase Obligation, Due in Fourth Year	188
Purchase Obligation, Due in Fifth Year	156
Purchase Obligation, Due after Fifth Year	805
Purchase Obligation	1,774
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	4
Operating Leases, Future Minimum Payments, Due in Three Years	4
Operating Leases, Future Minimum Payments, Due in Four Years	4
Operating Leases, Future Minimum Payments, Due in Five Years	4
Operating Leases, Future Minimum Payments, Due Thereafter	42
Operating Leases, Future Minimum Payments Due	63
Contractual Obligation, Due in Next Twelve Months	1,336
Contractual Obligation, Due in Second Year	1,005
Contractual Obligation, Due in Third Year	856
Contractual Obligation, Due in Fourth Year	819
Contractual Obligation, Due in Fifth Year	740
Contractual Obligation, Due after Fifth Year	4,437
Contractual Obligation	9,193
Rent expense for power purchase agreements meeting definition of operating lease	$ 13	$ 15	$ 24
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	$ 16	$ 16
PacifiCorp [Member] | Purchased electricity contracts - commercially operable
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	168
Purchase Obligation, Due in Second Year	71
Purchase Obligation, Due in Third Year	70
Purchase Obligation, Due in Fourth Year	67
Purchase Obligation, Due in Fifth Year	68
Purchase Obligation, Due after Fifth Year	401
Purchase Obligation	845
PacifiCorp [Member] | Purchased electricity contracts - not commercially operable
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	16
Purchase Obligation, Due in Second Year	102
Purchase Obligation, Due in Third Year	104
Purchase Obligation, Due in Fourth Year	104
Purchase Obligation, Due in Fifth Year	104
Purchase Obligation, Due after Fifth Year	1,687
Purchase Obligation	2,117
PacifiCorp [Member] | Fuel contracts
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	862
Purchase Obligation, Due in Second Year	689
Purchase Obligation, Due in Third Year	558
Purchase Obligation, Due in Fourth Year	542
Purchase Obligation, Due in Fifth Year	496
Purchase Obligation, Due after Fifth Year	1,720
Purchase Obligation	4,867
PacifiCorp [Member] | Capital Addition Purchase Commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	144
Purchase Obligation, Due in Second Year	12
Purchase Obligation, Due in Third Year	10
Purchase Obligation, Due in Fourth Year	2
Purchase Obligation, Due in Fifth Year	2
Purchase Obligation, Due after Fifth Year	5
Purchase Obligation	175
PacifiCorp [Member] | Transmission
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	105
Purchase Obligation, Due in Second Year	97
Purchase Obligation, Due in Third Year	91
Purchase Obligation, Due in Fourth Year	76
Purchase Obligation, Due in Fifth Year	55
Purchase Obligation, Due after Fifth Year	508
Purchase Obligation	932
PacifiCorp [Member] | Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	36
Purchase Obligation, Due in Second Year	30
Purchase Obligation, Due in Third Year	19
Purchase Obligation, Due in Fourth Year	24
Purchase Obligation, Due in Fifth Year	11
Purchase Obligation, Due after Fifth Year	74
Purchase Obligation	$ 194

Commitments and Contingencie266

Commitments and Contingencies - MEC - Commitments Table (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)number_of_projects	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Contractual Obligation [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 143
Operating Leases, Future Minimum Payments, Due in Two Years	118
Operating Leases, Future Minimum Payments, Due in Three Years	95
Operating Leases, Future Minimum Payments, Due in Four Years	77
Operating Leases, Future Minimum Payments, Due in Five Years	66
Operating Leases, Future Minimum Payments, Due Thereafter	1,007
Operating Leases, Future Minimum Payments Due	1,506
Contractual Obligation, Due in Next Twelve Months	4,082
Contractual Obligation, Due in Second Year	2,167
Contractual Obligation, Due in Third Year	1,631
Contractual Obligation, Due in Fourth Year	1,497
Contractual Obligation, Due in Fifth Year	1,354
Contractual Obligation, Due after Fifth Year	11,311
Contractual Obligation	22,042
Capital Addition Purchase Commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	1,544
Purchase Obligation, Due in Second Year	25
Purchase Obligation, Due in Third Year	11
Purchase Obligation, Due in Fourth Year	3
Purchase Obligation, Due in Fifth Year	3
Purchase Obligation, Due after Fifth Year	5
Purchase Obligation	1,591
Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	181
Purchase Obligation, Due in Second Year	264
Purchase Obligation, Due in Third Year	180
Purchase Obligation, Due in Fourth Year	188
Purchase Obligation, Due in Fifth Year	156
Purchase Obligation, Due after Fifth Year	805
Purchase Obligation	1,774
MidAmerican Energy Company [Member]
Contractual Obligation [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	17
Operating Leases, Future Minimum Payments, Due in Two Years	17
Operating Leases, Future Minimum Payments, Due in Three Years	17
Operating Leases, Future Minimum Payments, Due in Four Years	16
Operating Leases, Future Minimum Payments, Due in Five Years	15
Operating Leases, Future Minimum Payments, Due Thereafter	516
Operating Leases, Future Minimum Payments Due	598
Contractual Obligation, Due in Next Twelve Months	933
Contractual Obligation, Due in Second Year	298
Contractual Obligation, Due in Third Year	202
Contractual Obligation, Due in Fourth Year	139
Contractual Obligation, Due in Fifth Year	108
Contractual Obligation, Due after Fifth Year	869
Contractual Obligation	$ 2,549
Number of Construction Projects | number_of_projects	4
Operating leases, rent expense, net	$ 4	$ 4	$ 6
MidAmerican Energy Company [Member] | Fuel contracts
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	173
Purchase Obligation, Due in Second Year	113
Purchase Obligation, Due in Third Year	72
Purchase Obligation, Due in Fourth Year	29
Purchase Obligation, Due in Fifth Year	0
Purchase Obligation, Due after Fifth Year	0
Purchase Obligation	387
MidAmerican Energy Company [Member] | Electric capacity and transmission
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	30
Purchase Obligation, Due in Second Year	30
Purchase Obligation, Due in Third Year	11
Purchase Obligation, Due in Fourth Year	10
Purchase Obligation, Due in Fifth Year	10
Purchase Obligation, Due after Fifth Year	58
Purchase Obligation	149
MidAmerican Energy Company [Member] | Natural gas contracts for gas operations
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	131
Purchase Obligation, Due in Second Year	69
Purchase Obligation, Due in Third Year	31
Purchase Obligation, Due in Fourth Year	11
Purchase Obligation, Due in Fifth Year	10
Purchase Obligation, Due after Fifth Year	30
Purchase Obligation	282
MidAmerican Energy Company [Member] | Capital Addition Purchase Commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	535
Purchase Obligation, Due in Second Year	10
Purchase Obligation, Due in Third Year	0
Purchase Obligation, Due in Fourth Year	0
Purchase Obligation, Due in Fifth Year	0
Purchase Obligation, Due after Fifth Year	0
Purchase Obligation	545
MidAmerican Energy Company [Member] | Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	47
Purchase Obligation, Due in Second Year	59
Purchase Obligation, Due in Third Year	71
Purchase Obligation, Due in Fourth Year	73
Purchase Obligation, Due in Fifth Year	73
Purchase Obligation, Due after Fifth Year	265
Purchase Obligation	$ 588

Commitments and Contingencie267

Commitments and Contingencies - NPC - Legal (Details) - Nevada Power Company [Member]	1 Months Ended
	May. 31, 2014MW	Sep. 30, 2015power_purchase_agreements
Loss Contingencies [Line Items]
Number of Approved Renewable Power Purchase Agreements | power_purchase_agreements		2
210 Megawatts of Renewable Energy [Member]
Loss Contingencies [Line Items]
New Generation Capacity	210
300 Megawatts of Renewable Energy [Member]
Loss Contingencies [Line Items]
New Generation Capacity	300
272 Megawatts of Renewable Energy [Member]
Loss Contingencies [Line Items]
New Generation Capacity	272
15 Megawatts of Solar Renewable Energy [Member]
Loss Contingencies [Line Items]
New Generation Capacity	15

Commitments and Contingencie268

Commitments and Contingencies - NPC - Commitments Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Contractual Obligation [Line Items]
Contractual Obligation, Due in Next Twelve Months	$ 4,082
Contractual Obligation, Due in Second Year	2,167
Contractual Obligation, Due in Third Year	1,631
Contractual Obligation, Due in Fourth Year	1,497
Contractual Obligation, Due in Fifth Year	1,354
Contractual Obligation, Due after Fifth Year	11,311
Contractual Obligation	22,042
Operating Leases, Rent Expense	161	$ 146	$ 118
Fuel, capacity and transmission contract commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	2,214
Purchase Obligation, Due in Second Year	1,760
Purchase Obligation, Due in Third Year	1,345
Purchase Obligation, Due in Fourth Year	1,229
Purchase Obligation, Due in Fifth Year	1,129
Purchase Obligation, Due after Fifth Year	9,494
Purchase Obligation	17,171
Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	181
Purchase Obligation, Due in Second Year	264
Purchase Obligation, Due in Third Year	180
Purchase Obligation, Due in Fourth Year	188
Purchase Obligation, Due in Fifth Year	156
Purchase Obligation, Due after Fifth Year	805
Purchase Obligation	1,774
Nevada Power Company [Member]
Contractual Obligation [Line Items]
Contractual Obligation, Due in Next Twelve Months	669
Contractual Obligation, Due in Second Year	622
Contractual Obligation, Due in Third Year	399
Contractual Obligation, Due in Fourth Year	395
Contractual Obligation, Due in Fifth Year	402
Contractual Obligation, Due after Fifth Year	5,366
Contractual Obligation	7,853
Rent expense for power purchase agreements meeting definition of operating lease	264	245	400
Operating Leases, Rent Expense	11	$ 10	$ 9
Nevada Power Company [Member] | Fuel, capacity and transmission contract commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	612
Purchase Obligation, Due in Second Year	478
Purchase Obligation, Due in Third Year	330
Purchase Obligation, Due in Fourth Year	328
Purchase Obligation, Due in Fifth Year	330
Purchase Obligation, Due after Fifth Year	4,587
Purchase Obligation	6,665
Nevada Power Company [Member] | Fuel, capacity and transmission contract commitments, Not commercially operable
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	0
Purchase Obligation, Due in Second Year	20
Purchase Obligation, Due in Third Year	23
Purchase Obligation, Due in Fourth Year	23
Purchase Obligation, Due in Fifth Year	30
Purchase Obligation, Due after Fifth Year	603
Purchase Obligation	699
Nevada Power Company [Member] | Operating Leases, Easements, Maintenance and Service [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	11
Purchase Obligation, Due in Second Year	8
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	67
Purchase Obligation	108
Nevada Power Company [Member] | Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	46
Purchase Obligation, Due in Second Year	116
Purchase Obligation, Due in Third Year	38
Purchase Obligation, Due in Fourth Year	37
Purchase Obligation, Due in Fifth Year	35
Purchase Obligation, Due after Fifth Year	109
Purchase Obligation	$ 381

Commitments and Contingencie269

Commitments and Contingencies - SPPC - Legal (Details)	Dec. 31, 2015
Idaho Power Company [Member] | Valmy Generating Station [Member]
Loss Contingencies [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%

Commitments and Contingencie270

Commitments and Contingencies - SPPC - Commitments Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Contractual Obligation [Line Items]
Contractual Obligation, Due in Next Twelve Months	$ 4,082
Contractual Obligation, Due in Second Year	2,167
Contractual Obligation, Due in Third Year	1,631
Contractual Obligation, Due in Fourth Year	1,497
Contractual Obligation, Due in Fifth Year	1,354
Contractual Obligation, Due after Fifth Year	11,311
Contractual Obligation	22,042
Operating Leases, Rent Expense	161	$ 146	$ 118
Fuel, capacity and transmission contract commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	2,214
Purchase Obligation, Due in Second Year	1,760
Purchase Obligation, Due in Third Year	1,345
Purchase Obligation, Due in Fourth Year	1,229
Purchase Obligation, Due in Fifth Year	1,129
Purchase Obligation, Due after Fifth Year	9,494
Purchase Obligation	17,171
Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	181
Purchase Obligation, Due in Second Year	264
Purchase Obligation, Due in Third Year	180
Purchase Obligation, Due in Fourth Year	188
Purchase Obligation, Due in Fifth Year	156
Purchase Obligation, Due after Fifth Year	805
Purchase Obligation	1,774
Sierra Pacific Power Company [Member]
Contractual Obligation [Line Items]
Contractual Obligation, Due in Next Twelve Months	218
Contractual Obligation, Due in Second Year	167
Contractual Obligation, Due in Third Year	116
Contractual Obligation, Due in Fourth Year	96
Contractual Obligation, Due in Fifth Year	83
Contractual Obligation, Due after Fifth Year	531
Contractual Obligation	1,211
Rent expense for power purchase agreements meeting definition of operating lease	65	68	63
Operating Leases, Rent Expense	7	$ 6	$ 5
Sierra Pacific Power Company [Member] | Fuel, capacity and transmission contract commitments [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	207
Purchase Obligation, Due in Second Year	159
Purchase Obligation, Due in Third Year	109
Purchase Obligation, Due in Fourth Year	88
Purchase Obligation, Due in Fifth Year	75
Purchase Obligation, Due after Fifth Year	444
Purchase Obligation	1,082
Sierra Pacific Power Company [Member] | Operating Leases, Easements, Maintenance and Service [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	6
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	65
Purchase Obligation	84
Sierra Pacific Power Company [Member] | Maintenance, service and other contracts [Member]
Contractual Obligation [Line Items]
Purchase Obligation, Due in Next Twelve Months	5
Purchase Obligation, Due in Second Year	4
Purchase Obligation, Due in Third Year	4
Purchase Obligation, Due in Fourth Year	5
Purchase Obligation, Due in Fifth Year	5
Purchase Obligation, Due after Fifth Year	22
Purchase Obligation	$ 45

Preferred Stock - PacifiCorp (D

Preferred Stock - PacifiCorp (Details) - PacifiCorp [Member] $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2015Payments$ / sharesshares	Dec. 31, 2014$ / sharesshares	Dec. 31, 2013USD ($)
Class of Stock [Line Items]
Stock Redeemed or Called During Period, Value | $			$ 40
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%
Redeemable Preferred Stock [Member]
Class of Stock [Line Items]
Stock Redeemed or Called During Period, Value | $			$ 40

Preferred Stock Preferred Stock

Preferred Stock Preferred Stock - MEC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
MidAmerican Energy Company [Member]
Class of Stock [Line Items]
Stock Redeemed or Called During Period, Value	$ 28	$ 28

BHE Shareholders' Equity (Detai

BHE Shareholders' Equity (Details) - USD ($) $ in Millions	2 Months Ended	12 Months Ended
	Feb. 28, 2015	Dec. 31, 2015	Dec. 31, 2013
Class of Stock [Line Items]
Common stock, value, issued			$ 1,000
Common stock, value, repurchased		$ (36)
Common Stock [Member]
Class of Stock [Line Items]
Common stock, value, issued			$ 1,000
Common stock issuances (shares)			2,857,143
Common stock repurchased (shares)	75,000
Common stock, value, repurchased	$ 36

BHE Shareholders' Equity - Rest

BHE Shareholders' Equity - Restricted Net Assets (Details) $ in Billions	Dec. 31, 2015USD ($)
Stockholders' Equity Note [Abstract]
BHE restricted net assets	$ 12.7
BHE's subsidiaries restricted net assets	$ 17.2

Common Shareholder's Equity - P

Common Shareholder's Equity - PacifiCorp (Details) - PacifiCorp [Member] - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Feb. 29, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Class of Stock [Line Items]
Dividends, Common Stock, Cash		$ 950	$ 725	$ 500
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		52.00%
Amount available for dividend distribution without prior approval		$ 2,000
Subsequent Event [Member]
Class of Stock [Line Items]
Dividends, Common Stock, Cash	$ 100

Components of Accumulated Ot276

Components of Accumulated Other Comprehensive Loss, Net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	$ (494)
Other comprehensive (loss) income, unrecognized amounts on retirement benefits	52	$ 69	$ 16
Other comprehensive (loss) income, foreign currency translation adjustment	(680)	(314)	74
Other comprehensive (loss) income, unrealized gains on available-for-sale securities	225	(134)	263
Other comprehensive (loss) income, unrealized gains on cash flow hedges	(11)	(18)	13
Other comprehensive income (loss)	(414)	(397)	366
Ending balance	(908)	(494)
Accumulated Other Comprehensive Loss, Net [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance, unrecognized amounts on retirement benefits	(490)	(559)	(575)
Balance, foreign currency translation adjustment	(412)	(98)	(172)
Beginning balance	390	524	261
Beginning balance	18	36	23
Beginning balance	(494)	(97)	(463)
Other comprehensive (loss) income, unrecognized amounts on retirement benefits	52	69	16
Other comprehensive (loss) income, foreign currency translation adjustment	(680)	(314)	74
Other comprehensive (loss) income, unrealized gains on available-for-sale securities	225	(134)	263
Other comprehensive (loss) income, unrealized gains on cash flow hedges	(11)	(18)	13
Other comprehensive income (loss)	(414)	(397)	366
Balance, unrecognized amounts on retirement benefits	(438)	(490)	(559)
Balance, foreign currency translation adjustment	(1,092)	(412)	(98)
Ending balance	615	390	524
Ending balance	7	18	36
Ending balance	$ (908)	$ (494)	$ (97)

Components of Accumulated Ot277

Components of Accumulated Other Comprehensive Loss, Net - PacifiCorp (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
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	$ (11)	$ (13)

Components of Accumulated Ot278

Components of Accumulated Other Comprehensive Loss, Net - MEC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of accumulated other comprehensive income (loss)
Beginning balance	$ (494)
Unrealized gains (losses) on available-for-sale securities, net of tax	225	$ (134)	$ 263
Unrealized (losses) gains on cash flow hedges, net of tax	(11)	(18)	13
Other comprehensive (loss) income, net of tax	(414)	(397)	366
Ending balance	(908)	(494)
MidAmerican Energy Company [Member]
Schedule of accumulated other comprehensive income (loss)
Beginning balance	(23)
Unrealized gains (losses) on available-for-sale securities, net of tax	0	1	1
Unrealized (losses) gains on cash flow hedges, net of tax	(7)	(13)	12
Other comprehensive (loss) income, net of tax	(7)	(12)	13
Ending balance	(30)	(23)
Accumulated Other Comprehensive Income (Loss) [Member]
Schedule of accumulated other comprehensive income (loss)
Beginning balance	390	524	261
Beginning balance	18	36	23
Beginning balance	(494)	(97)	(463)
Unrealized gains (losses) on available-for-sale securities, net of tax	225	(134)	263
Unrealized (losses) gains on cash flow hedges, net of tax	(11)	(18)	13
Other comprehensive (loss) income, net of tax	(414)	(397)	366
Ending balance	615	390	524
Ending balance	7	18	36
Ending balance	(908)	(494)	(97)
Accumulated Other Comprehensive Income (Loss) [Member] | MidAmerican Energy Company [Member]
Schedule of accumulated other comprehensive income (loss)
Beginning balance	(3)	(4)
Beginning balance	(20)	(7)
Beginning balance	(23)	(11)
Unrealized gains (losses) on available-for-sale securities, net of tax	0	1
Unrealized (losses) gains on cash flow hedges, net of tax	(7)	(13)
Other comprehensive (loss) income, net of tax	(7)	(12)	13
Ending balance	(3)	(3)	(4)
Ending balance	(27)	(20)	(7)
Ending balance	$ (30)	$ (23)	$ (11)

Variable-Interest Entities - Pa

Variable-Interest Entities - PacifiCorp (Details) - PacifiCorp [Member] - USD ($)		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Variable Interest Entity (VIE) or Potential VIE, Information Unavailability [Member]
Schedule of Equity Method Investments [Line Items]
Variable Interest Entity, Measure of Activity, Purchases		$ 39,000,000	$ 38,000,000	$ 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		$ 190,000,000	$ 192,000,000
Hermiston [Member]
Schedule of Equity Method Investments [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	[1]	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%
[1]	(1)As discussed in Note 17, PacifiCorp has contracted to purchase the remaining 50% of the output of the Hermiston generating facility.

Noncontrolling Interests (Detai

Noncontrolling Interests (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Preferred Securities of Subsidiaries [Line Items]
Preferred stock of subsidiaries, value, outstanding noncontrolling interest, amount represented by preferred stock	$ 58	$ 58
Stock Redeemed or Called During Period, Value			$ 68
PacifiCorp [Member]
Preferred Securities of Subsidiaries [Line Items]
Preferred stock of subsidiaries, value, outstanding noncontrolling interest, amount represented by preferred stock	2	2
Stock Redeemed or Called During Period, Value			40
MidAmerican Energy Company [Member]
Preferred Securities of Subsidiaries [Line Items]
Stock Redeemed or Called During Period, Value			$ 28
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, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Sales revenue from energy operations		$ 15,354	$ 15,182	$ 10,826
Real estate		2,526	2,144	1,809
Revenues		17,880	17,326	12,635
Depreciation and amortization - energy operations		2,399	2,028	1,527
Depreciation and amortization		2,428	2,057	1,560
Operating income (loss)		4,328	4,046	2,835
Interest expense		1,904	1,711	1,222
Capitalized interest		74	89	84
Allowance for equity funds		91	98	78
Investment Income, Interest and Dividend		107	38	15
Other, net		39	42	51
Income before income tax expense and equity income		2,735	2,602	1,841
Income tax expense		450	589	130
Payments to Acquire Property, Plant, and Equipment		5,875	6,555	4,307
Property, plant and equipment, net		60,769	59,248	50,119
Assets		83,618	81,816	69,591
PacifiCorp [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		5,232	5,252	5,147
Depreciation and amortization - energy operations		780	745	692
Operating income (loss)		1,344	1,308	1,275
Interest expense		383	386	390
Income tax expense		328	310	298
Payments to Acquire Property, Plant, and Equipment		916	1,066	1,065
Property, plant and equipment, net		19,039	18,755	18,563
Assets		23,550	23,404	22,781
MidAmerican Funding [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		3,420	3,762	3,413
Depreciation and amortization - energy operations		407	351	403
Operating income (loss)		473	423	357
Interest expense		206	197	174
Income tax expense		(144)	(110)	(110)
Payments to Acquire Property, Plant, and Equipment		1,448	1,527	1,027
Property, plant and equipment, net		11,737	10,535	9,353
Assets		16,499	15,346	13,970
NV Energy [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		3,351	3,241	(20)
Depreciation and amortization - energy operations		410	379	0
Operating income (loss)		812	791	(42)
Interest expense		262	283	0
Income tax expense		207	195	(15)
Payments to Acquire Property, Plant, and Equipment		571	558	0
Property, plant and equipment, net		9,767	9,648	9,623
Assets		14,656	14,256	14,016
Northern Powergrid Holdings [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		1,140	1,283	1,025
Depreciation and amortization - energy operations		202	198	180
Operating income (loss)		593	674	501
Interest expense		145	151	141
Income tax expense		35	110	23
Payments to Acquire Property, Plant, and Equipment		674	675	675
Property, plant and equipment, net		5,790	5,599	5,476
Assets		7,317	7,059	6,852
BHE Pipeline Group [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		1,016	1,078	952
Depreciation and amortization - energy operations		204	196	190
Operating income (loss)		464	439	446
Interest expense		66	76	80
Income tax expense		158	149	149
Payments to Acquire Property, Plant, and Equipment		240	257	177
Property, plant and equipment, net		4,345	4,286	4,147
Assets		4,953	4,951	4,891
BHE Transmission [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		592	62	0
Depreciation and amortization - energy operations		185	13	0
Operating income (loss)		260	16	(5)
Interest expense		146	14	0
Income tax expense		63	28	10
Payments to Acquire Property, Plant, and Equipment		966	222	0
Property, plant and equipment, net		5,301	5,567	0
Assets		7,553	7,979	465
BHE Renewables [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations		728	623	355
Depreciation and amortization - energy operations		216	152	71
Operating income (loss)		255	314	223
Interest expense		193	175	138
Income tax expense		41	65	57
Payments to Acquire Property, Plant, and Equipment		1,034	2,221	1,329
Property, plant and equipment, net		4,805	4,897	3,020
Assets		5,892	6,082	3,832
HomeServices [Member]
Segment Reporting Information [Line Items]
Real estate		2,526	2,144	1,809
Depreciation and amortization		29	29	33
Operating income (loss)		184	125	129
Interest expense		3	4	3
Income tax expense		72	44	48
Payments to Acquire Property, Plant, and Equipment		16	17	21
Property, plant and equipment, net		70	68	61
Assets		1,705	1,622	1,375
Other [Member]
Segment Reporting Information [Line Items]
Sales revenue from energy operations	[1]	(125)	(119)	(46)
Depreciation and amortization - energy operations	[1]	(5)	(6)	(9)
Operating income (loss)	[1]	(57)	(44)	(49)
Interest expense	[1]	500	425	296
Income tax expense	[1]	(310)	(202)	(330)
Payments to Acquire Property, Plant, and Equipment		10	12	13
Property, plant and equipment, net		(85)	(107)	(124)
Assets		1,493	1,117	1,409
UNITED STATES
Segment Reporting Information [Line Items]
Revenues		16,121	15,857	11,465
Income before income tax expense and equity income		2,034	2,001	1,388
Property, plant and equipment, net		49,680	47,918	44,460
United Kingdom
Segment Reporting Information [Line Items]
Revenues		1,140	1,281	1,023
Income before income tax expense and equity income		472	557	373
Property, plant and equipment, net		5,757	5,563	5,439
CANADA
Segment Reporting Information [Line Items]
Revenues		600	78	16
Income before income tax expense and equity income		165	4	0
Property, plant and equipment, net		5,298	5,570	3
The Philippines and other [Member]
Segment Reporting Information [Line Items]
Revenues		19	110	131
Income before income tax expense and equity income		64	40	80
Property, plant and equipment, net		$ 34	$ 197	$ 217
[1]	(1)The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other, relate to other corporate entities, corporate functions and intersegment eliminations.

Segment Information - Goodwill

Segment Information - Goodwill (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Goodwill [Roll Forward]
Beginning balance	$ 9,343	$ 7,527
Acquisitions	77	1,935
Foreign currency translation	(318)	(93)
Other	(26)	(26)
Ending balance	9,076	9,343
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	2,280
Acquisitions	0	89
Foreign currency translation	0	0
Other	0	0
Ending balance	2,369	2,369
Northern Powergrid Holdings [Member]
Goodwill [Roll Forward]
Beginning balance	1,100	1,149
Acquisitions	0	0
Foreign currency translation	(44)	(49)
Other	0	0
Ending balance	1,056	1,100
BHE Pipeline Group [Member]
Goodwill [Roll Forward]
Beginning balance	127	153
Acquisitions	0	0
Foreign currency translation	0	0
Other	(26)	(26)
Ending balance	101	127
BHE Transmission [Member]
Goodwill [Roll Forward]
Beginning balance	1,657	0
Acquisitions	44	1,700
Foreign currency translation	(273)	(43)
Other	0	0
Ending balance	1,428	1,657
BHE Renewables [Member]
Goodwill [Roll Forward]
Beginning balance	95	15
Acquisitions	0	80
Foreign currency translation	0	0
Other	0	0
Ending balance	95	95
HomeServices [Member]
Goodwill [Roll Forward]
Beginning balance	761	695
Acquisitions	33	66
Foreign currency translation	0	0
Other	0	0
Ending balance	794	761
Other [Member]
Goodwill [Roll Forward]
Beginning balance	3	4
Acquisitions	0	0
Foreign currency translation	(1)	(1)
Other	0	0
Ending balance	$ 2	$ 3

Segment Information - MEC (Deta

Segment Information - MEC (Details) $ in Millions	3 Months Ended							9 Months Ended	12 Months Ended
	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Sep. 30, 2014USD ($)	Dec. 31, 2015USD ($)OperatingSegmentsTheNumberOfReportableSegments	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | OperatingSegments									8
Revenues									$ 17,880	$ 17,326	$ 12,635
Operating income (loss)									4,328	4,046	2,835
Interest expense									1,904	1,711	1,222
Income tax (benefit) expense									450	589	130
Payments to Acquire Property, Plant, and Equipment									5,875	6,555	4,307
Assets	$ 83,618				$ 81,816				$ 83,618	81,816	69,591
MidAmerican Energy Company [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | TheNumberOfReportableSegments									3
Electric Domestic Regulated Revenue									$ 1,837	1,817	1,762
Gas Domestic Regulated Revenue									661	996	824
Other Revenue, Net									909	927	817
Revenues	748	$ 920	$ 793	$ 946	884	$ 769	$ 1,225	$ 862	3,407	3,740	3,403
Utilities Operating Expense, Depreciation and Amortization									407	351	403
Operating income (loss)	33	$ 210	$ 122	$ 106	58	$ 51	$ 153	$ 160	471	422	356
Interest expense									183	174	151
Income tax (benefit) expense									(141)	(104)	(103)
Net Income (Loss) Available to Common Stockholders, Basic									462	417	349
Payments to Acquire Property, Plant, and Equipment									1,446	1,526	1,026
Assets	14,385				13,234				14,385	13,234	11,848
MidAmerican Energy Company [Member] | Regulated Electric [Member]
Segment Reporting Information [Line Items]
Electric Domestic Regulated Revenue									1,837	1,817	1,762
Utilities Operating Expense, Depreciation and Amortization									366	312	366
Operating income (loss)									385	319	255
Interest expense									166	157	136
Income tax (benefit) expense									(163)	(138)	(136)
Net Income (Loss) Available to Common Stockholders, Basic									413	361	292
Payments to Acquire Property, Plant, and Equipment									1,365	1,429	945
Assets	12,970				11,850				12,970	11,850	10,521
MidAmerican Energy Company [Member] | Regulated Gas [Member]
Segment Reporting Information [Line Items]
Gas Domestic Regulated Revenue									661	996	824
Utilities Operating Expense, Depreciation and Amortization									41	39	37
Operating income (loss)									64	75	74
Interest expense									17	17	15
Income tax (benefit) expense									16	22	23
Net Income (Loss) Available to Common Stockholders, Basic									33	40	41
Payments to Acquire Property, Plant, and Equipment									81	97	81
Assets	1,251				1,217				1,251	1,217	1,196
MidAmerican Energy Company [Member] | Nonregulated Energy [Member]
Segment Reporting Information [Line Items]
Other Revenue, Net									909	927	817
Operating income (loss)									22	28	27
Income tax (benefit) expense									6	12	10
Net Income (Loss) Available to Common Stockholders, Basic									16	16	16
Assets	$ 164				$ 167				$ 164	$ 167	$ 131

Segment Information - MidAmeric

Segment Information - MidAmerican Funding (Details) $ in Millions	3 Months Ended							9 Months Ended	12 Months Ended
	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Sep. 30, 2014USD ($)	Dec. 31, 2015USD ($)OperatingSegmentsTheNumberOfReportableSegments	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | OperatingSegments									8
Revenues									$ 17,880	$ 17,326	$ 12,635
Operating income (loss)									4,328	4,046	2,835
Interest expense									1,904	1,711	1,222
Income tax (benefit) expense									450	589	130
Net income (loss) attributable to parent									2,370	2,095	1,636
Payments to Acquire Property, Plant, and Equipment									5,875	6,555	4,307
Assets	$ 83,618				$ 81,816				83,618	81,816	69,591
Goodwill	9,076				9,343				$ 9,076	9,343	7,527
MidAmerican Funding, LLC and Subsidiaries [Domain]
Segment Reporting Information [Line Items]
Number of Reportable Segments | TheNumberOfReportableSegments									3
Electric Domestic Regulated Revenue									$ 1,837	1,817	1,762
Gas Domestic Regulated Revenue									661	996	824
Other Revenue, Net									922	949	827
Revenues	751	$ 921	$ 797	$ 951	893	$ 775	$ 1,230	$ 864	3,420	3,762	3,413
Utilities Operating Expense, Depreciation and Amortization									407	351	403
Operating income (loss)	33	$ 211	$ 122	$ 107	58	$ 51	$ 153	$ 161	473	423	357
Interest expense									206	197	174
Income tax (benefit) expense									(144)	(110)	(110)
Net income (loss) attributable to parent									458	409	340
Payments to Acquire Property, Plant, and Equipment									1,446	1,526	1,026
Assets	15,674				14,522				15,674	14,522	13,146
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									1,837	1,817	1,762
Utilities Operating Expense, Depreciation and Amortization									366	312	366
Operating income (loss)									385	319	255
Interest expense									166	157	136
Income tax (benefit) expense									(163)	(138)	(136)
Net income (loss) attributable to parent									413	361	292
Payments to Acquire Property, Plant, and Equipment									1,365	1,429	945
Assets	14,161				13,041				14,161	13,041	11,712
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									661	996	824
Utilities Operating Expense, Depreciation and Amortization									41	39	37
Operating income (loss)									64	75	74
Interest expense									17	17	15
Income tax (benefit) expense									16	22	23
Net income (loss) attributable to parent									33	40	41
Payments to Acquire Property, Plant, and Equipment									81	97	81
Assets	1,330				1,296				1,330	1,296	1,275
Goodwill	79				79				79	79
MidAmerican Funding, LLC and Subsidiaries [Domain] | Nonregulated Energy [Member]
Segment Reporting Information [Line Items]
Other Revenue, Net									910	927	817
Operating income (loss)									22	28	27
Income tax (benefit) expense									6	12	10
Net income (loss) attributable to parent									16	16	16
Assets	164				167				164	167	131
MidAmerican Funding, LLC and Subsidiaries [Domain] | Corporate and Other [Member]
Segment Reporting Information [Line Items]
Other Revenue, Net									12	22	10
Operating income (loss)									2	1	1
Interest expense									23	23	23
Income tax (benefit) expense									(3)	(6)	(7)
Net income (loss) attributable to parent									(4)	(8)	(9)
Assets	$ 19				$ 18				$ 19	$ 18	$ 28

Segment Information - SPPC (Det

Segment Information - SPPC (Details) $ in Millions		12 Months Ended
		Dec. 31, 2015USD ($)OperatingSegmentsTheNumberOfReportableSegments	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | OperatingSegments		8
Revenues		$ 17,880	$ 17,326	$ 12,635
Cost of sales		5,079	5,732	3,799
Operating income (loss)		4,328	4,046	2,835
Income tax expense		450	589	130
Payments to Acquire Property, Plant, and Equipment		5,875	6,555	4,307
Assets		$ 83,618	81,816	69,591
Sierra Pacific Power Company [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | TheNumberOfReportableSegments		2
Electric Domestic Regulated Revenue		$ 810	779	747
Gas Domestic Regulated Revenue		137	125	106
Revenues		947	904	853
Cost of sales		374	361	292
Cost of Purchased Oil and Gas		84	76	56
Cost of Sales		458	437	348
Gross Margin		489	467	505
Operations and maintenance		163	158	197
Utilities Operating Expense, Depreciation and Amortization		113	105	123
Operating income (loss)		184	178	140
Interest expense, net of borrowed funds		61	61	61
Income tax expense		47	47	33
Payments to Acquire Property, Plant, and Equipment		252	186	139
Assets		3,487	3,336	3,311
Sierra Pacific Power Company [Member] | Electric Operations [Member]
Segment Reporting Information [Line Items]
Electric Domestic Regulated Revenue		810	779	747
Cost of sales		374	361	292
Electric Domestic Regulated Gross Margin		436	418	455
Electricity, Utilities Operating Expense, Maintenance and Operations		146	140	176
Utilities Operating Expense, Depreciation and Amortization		96	90	106
Operating income (loss)		168	165	134
Electric, Interest Expense, net of allowance for borrowed funds		56	57	56
Income tax expense		43	43	32
Payments to Acquire Property, Plant, and Equipment		229	168	125
Assets		3,060	2,984	2,905
Sierra Pacific Power Company [Member] | Natural Gas Operations [Member]
Segment Reporting Information [Line Items]
Gas Domestic Regulated Revenue		137	125	106
Cost of Purchased Oil and Gas		84	76	56
Gas Domestic Regulated Gross Margin		53	49	50
Gas, Utilities Operating Expense, Maintenance and Operations		17	18	21
Utilities Operating Expense, Depreciation and Amortization		17	15	17
Operating income (loss)		16	13	6
Gas, Interest Expense, net of allowance for borrowed funds		5	4	5
Income tax expense		4	4	1
Payments to Acquire Property, Plant, and Equipment		23	18	14
Assets		316	322	329
Sierra Pacific Power Company [Member] | Regulated common assets [Member]
Segment Reporting Information [Line Items]
Assets	[1]	$ 111	$ 30	$ 77
[1]	Consists principally of cash and cash equivalents not included in either the regulated electric or regulated natural gas segments.

Transfer of Nonregulated Ene286

Transfer of Nonregulated Energy Operations Transfer of Nonregulated Energy Operations - MEC (Details) - Unregulated Retail Services [Member] - MidAmerican Energy Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Subsequent Event [Line Items]
Unregulated retail services net assets	$ 88
Unregulated retail services operating revenue	905
Unregulated retail services operating income	22
Unregulated retail services net income	16
Unregulated retail services cash flows from operating activities	$ 30

Unaudited Quarterly Operatin287

Unaudited Quarterly Operating Results - MEC (Details) - USD ($) $ in Millions	3 Months Ended							9 Months Ended	12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Jun. 30, 2014	Mar. 31, 2014	Sep. 30, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Quarterly Operating Results [Line Items]
Revenues									$ 17,880	$ 17,326	$ 12,635
Operating income (loss)									4,328	4,046	2,835
Net income									2,400	2,122	1,676
MidAmerican Energy Company [Member]
Quarterly Operating Results [Line Items]
Revenues	$ 748	$ 920	$ 793	$ 946	$ 884	$ 769	$ 1,225	$ 862	3,407	3,740	3,403
Operating income (loss)	33	210	122	106	58	51	153	160	471	422	356
Net income	$ 3	$ 234	$ 131	$ 94	$ 58	$ 32	$ 157	$ 170	$ 462	$ 417	$ 350

Unaudited Quarterly Operatin288

Unaudited Quarterly Operating Results - MidAmerican Funding (Details) - USD ($) $ in Millions	3 Months Ended							9 Months Ended	12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Jun. 30, 2014	Mar. 31, 2014	Sep. 30, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Quarterly Operating Results [Line Items]
Revenues									$ 17,880	$ 17,326	$ 12,635
Operating income (loss)									4,328	4,046	2,835
Net income									2,400	2,122	1,676
MidAmerican Funding, LLC and Subsidiaries [Domain]
Quarterly Operating Results [Line Items]
Revenues	$ 751	$ 921	$ 797	$ 951	$ 893	$ 775	$ 1,230	$ 864	3,420	3,762	3,413
Operating income (loss)	33	211	122	107	58	51	153	161	473	423	357
Net income	$ (1)	$ 231	$ 129	$ 99	$ 56	$ 30	$ 155	$ 168	$ 458	$ 409	$ 341

Unaudited Quarterly Operatin289

Unaudited Quarterly Operating Results - NPC (Details) - USD ($) $ in Millions	3 Months Ended							9 Months Ended	12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Jun. 30, 2014	Mar. 31, 2014	Sep. 30, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Quarterly Operating Results [Line Items]
Operating income (loss)									$ 4,328	$ 4,046	$ 2,835
Net income attributable to BHE shareholders									2,370	2,095	1,636
Nevada Power Company [Member]
Quarterly Operating Results [Line Items]
Electric Domestic Regulated Revenue	$ 458	$ 878	$ 607	$ 459	$ 458	$ 595	$ 417	$ 867	2,402	2,337	2,092
Operating income (loss)	74	329	136	74	34	145	55	307	613	541	435
Net income attributable to BHE shareholders	$ 17	$ 187	$ 60	$ 24	$ (9)	$ 62	$ 6	$ 168	$ 288	$ 227	$ 145

Unaudited Quarterly Operatin290

Unaudited Quarterly Operating Results - SPPC (Details) - Sierra Pacific Power Company [Member] - USD ($) $ in Millions	3 Months Ended							9 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Jun. 30, 2014	Mar. 31, 2014	Sep. 30, 2014
Quarterly Operating Results [Line Items]
Electric Domestic Operating Revenue, Quarterly	$ 185	$ 228	$ 201	$ 196	$ 190	$ 179	$ 177	$ 233
Gas Domestic Operating Revenue, Quarterly	43	18	26	50	42	21	44	18
Operating Income (loss), Quarterly	38	66	37	43	41	31	46	60
Net Income (Loss) Attributable to Parent, Quarterly	$ 15	$ 33	$ 16	$ 19	$ 20	$ 14	$ 22	$ 31

Schedule I Condensed Balance291

Schedule I Condensed Balance Sheets (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current assets:
Cash and cash equivalents		$ 1,108	$ 617	$ 1,175	$ 776
Accounts receivable		1,785	1,837
Income tax receivable		319	1,156
Other current assets		814	930
Total current assets		5,243	5,652
Goodwill		9,076	9,343	7,527
Other assets		1,008	770
Total assets		83,618	81,816	69,591
Current liabilities:
Short-term debt	[1]	974	1,445
Total current liabilities		6,089	7,109
BHE senior debt		7,814	7,810
BHE junior subordinated debentures		2,944	3,794
Long-term Debt		37,972	38,649
Other long-term liabilities		2,854	2,731
Total liabilities		61,083	61,243
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		6,403	6,423
Retained earnings		16,906	14,513
Accumulated other comprehensive loss, net		(908)	(494)
Total shareholders' equity		22,401	20,442
Noncontrolling interest		134	131
Total equity		22,535	20,573	18,816	15,910
Total liabilities and equity		83,618	81,816
MidAmerican Funding LLC [Member]
Current assets:
Cash and cash equivalents		0	0	0	0
Due from Affiliates		2	2
Investments in subsidiaries		6,144	5,679
Total assets		6,146	5,681
Current liabilities:
Other accrued current liabilities		7	8
Long-term Debt		326	326
Notes payable - affiliate		288	274
Total liabilities		621	608
Shareholders' equity:
Paid-in capital		1,679	1,679
Retained earnings		3,876	3,417
Accumulated other comprehensive loss, net		(30)	(23)
Total shareholders' equity		5,525	5,073
Total liabilities and equity		6,146	5,681
Parent Company [Member]
Current assets:
Cash and cash equivalents		23	3	$ 292	$ 13
Accounts receivable		16	22
Income tax receivable		167	152
Other current assets		2	1
Total current assets		208	178
Investments in subsidiaries		32,505	31,968
Other Investments		1,389	1,038
Goodwill		1,221	1,221
Other assets		1,340	1,176
Total assets		36,663	35,581
Current liabilities:
Accounts payable and other current liabilities		306	308
Short-term debt		253	395
Total current liabilities		559	703
BHE senior debt		7,814	7,810
BHE junior subordinated debentures		2,944	3,794
Notes payable - affiliate		1,985	1,981
Other long-term liabilities		946	839
Total liabilities		14,248	15,127
Shareholders' equity:
Common stock		0	0
Additional paid-in capital		6,403	6,423
Retained earnings		16,906	14,513
Accumulated other comprehensive loss, net		(908)	(494)
Total shareholders' equity		22,401	20,442
Noncontrolling interest		14	12
Total equity		22,415	20,454
Total liabilities and equity		$ 36,663	$ 35,581
[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, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating costs and expenses:
Depreciation and amortization	$ 2,428	$ 2,057	$ 1,560
Total operating costs and expenses	13,552	13,280	9,800
Operating loss	4,328	4,046	2,835
Other income (expense):
Interest expense	(1,904)	(1,711)	(1,222)
Other, net	39	42	51
Total other income (expense)	(1,593)	(1,444)	(994)
Loss before income tax benefit and equity income	2,735	2,602	1,841
Income tax (benefit) expense	450	589	130
Equity income (loss)	115	109	(35)
Net income	2,400	2,122	1,676
Net income attributable to noncontrolling interests	30	27	40
Net income attributable to BHE shareholders	2,370	2,095	1,636
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	(8)	(9)	(9)
Equity income (loss)	472	422	353
Net income attributable to BHE shareholders	458	409	340
Parent Company [Member]
Operating costs and expenses:
General and administration	58	51	64
Depreciation and amortization	3	3	1
Total operating costs and expenses	61	54	65
Operating loss	(61)	(54)	(65)
Other income (expense):
Interest expense	(556)	(476)	(347)
Other, net	14	4	25
Total other income (expense)	(542)	(472)	(322)
Loss before income tax benefit and equity income	(603)	(526)	(387)
Income tax (benefit) expense	(330)	(221)	(345)
Equity income (loss)	2,646	2,402	1,679
Net income	2,373	2,097	1,637
Net income attributable to noncontrolling interests	3	2	1
Net income attributable to BHE shareholders	$ 2,370	$ 2,095	$ 1,636

Schedule I Condensed Stateme293

Schedule I Condensed Statements of Comprehensive Income Schedule I Condensed Statements of Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Net income attributable to BHE shareholders	$ 2,370	$ 2,095	$ 1,636
Net income	2,400	2,122	1,676
Other comprehensive (loss) income, net of tax	(414)	(397)	366
Comprehensive income	1,986	1,725	2,042
Comprehensive income attributable to noncontrolling interests	30	27	40
Comprehensive income attributable to BHE shareholders	1,956	1,698	2,002
MidAmerican Funding LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Net income attributable to BHE shareholders	458	409	340
Other comprehensive (loss) income, net of tax	(7)	(12)	13
Comprehensive income attributable to BHE shareholders	451	397	353
Parent Company [Member]
Condensed Financial Statements, Captions [Line Items]
Net income attributable to BHE shareholders	2,370	2,095	1,636
Net income	2,373	2,097	1,637
Other comprehensive (loss) income, net of tax	(414)	(397)	366
Comprehensive income	1,959	1,700	2,003
Comprehensive income attributable to noncontrolling interests	3	2	1
Comprehensive income attributable to BHE shareholders	$ 1,956	$ 1,698	$ 2,002

Schedule I Condensed Stateme294

Schedule I Condensed Statements of Cash Flows Schedule I Condensed Statements of Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	$ 6,980	$ 5,146	$ 4,669
Cash flows from investing activities:
Purchases of available-for-sale securities	(144)	(150)	(228)
Proceeds from sale of investments	142	118	191
Other, net	41	(11)	13
Net cash flows from investing activities	(6,230)	(9,418)	(10,194)
Cash flows from financing activities:
Proceeds from BHE senior debt	0	1,478	1,981
Proceeds from BHE junior subordinated debentures	0	1,500	2,594
Proceeds from issuance of BHE common stock	0	0	1,000
Payments for Repurchase of Common Stock	36	0	0
Net (repayments of) proceeds from short-term debt	(421)	1,055	(849)
Other, net	(73)	(44)	(104)
Net cash flows from financing activities	(255)	3,725	5,926
Net change in cash and cash equivalents	491	(558)	399
Cash and cash equivalents at beginning of period	617	1,175	776
Cash and cash equivalents at end of period	1,108	617	1,175
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	2,528	1,937	2,295
Cash flows from investing activities:
Investments in subsidiaries	(1,506)	(4,937)	(6,522)
Purchases of available-for-sale securities	(36)	(56)	(106)
Proceeds from sale of investments	47	35	89
Notes receivable from affiliate, net	19	(55)	(37)
Other, net	(7)	(7)	(16)
Net cash flows from investing activities	(1,483)	(5,020)	(6,592)
Cash flows from financing activities:
Proceeds from BHE senior debt	0	1,478	1,981
Proceeds from BHE junior subordinated debentures	0	1,500	2,594
Proceeds from issuance of BHE common stock	0	0	1,000
Repayments of BHE senior debt	0	(250)	0
Repayments of BHE subordinated debt	(850)	(300)	0
Payments for Repurchase of Common Stock	36	0	0
Net (repayments of) proceeds from short-term debt	(142)	395	(825)
Notes payable to affiliate, net	4	(30)	(173)
Other, net	(1)	1	(1)
Net cash flows from financing activities	(1,025)	2,794	4,576
Net change in cash and cash equivalents	20	(289)	279
Cash and cash equivalents at beginning of period	3	292	13
Cash and cash equivalents at end of period	$ 23	$ 3	$ 292

Condensed Financial Statemen295

Condensed Financial Statements - Other Investments (Details) - BYD Company Limited common stock [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Available-for-sale Securities, Equity Securities	$ 1,238	$ 881
Available-for-sale Securities, Change in Net Unrealized Holding Gain (Loss) before Taxes	1,000	649
Parent Company [Member]
Investments, Including Equity Method And Restricted Cash And Investments [Line Items]
Available-for-sale Securities, Equity Securities	1,200	881
Available-for-sale Securities, Change in Net Unrealized Holding Gain (Loss) before Taxes	$ 1,000	$ 649

Condensed Financial Statemen296

Condensed Financial Statements - Dividends and Distributions (Details) - Parent Company [Member] - USD ($) $ in Millions	2 Months Ended	12 Months Ended
	Feb. 26, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Distribution [Line Items]
Proceeds from dividends received		$ 3,000	$ 2,300	$ 2,500
Subsequent Event [Member]
Distribution [Line Items]
Proceeds from dividends received	$ 187

Condensed Financial Statemen297

Condensed Financial Statements - Guarantees (Details) - Parent Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Guarantor obligations, related party disclosure	$ 92
Tax Equity Contributions	$ 478

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, 2015	Dec. 31, 2014	Dec. 31, 2013
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 Val299

Schedule II Consolidated Valuation and Qualifying Accounts (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Allowance for Doubtful Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year		$ 37	$ 33	$ 22
Valuation Allowances and Reserves, Charged to Cost and Expense		33	37	23
Valuation Allowances and Reserves, Adjustments		0	0	9
Valuation Allowances and Reserves, Deductions		(39)	(33)	(21)
Balance at End of Year		31	37	33
Reserves not deducted from assets [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year	[1]	11	9	9
Valuation Allowances and Reserves, Charged to Cost and Expense	[1]	7	12	6
Valuation Allowances and Reserves, Adjustments	[1]	0	0	0
Valuation Allowances and Reserves, Deductions	[1]	(5)	(10)	(6)
Balance at End of Year	[1]	$ 13	$ 11	$ 9
[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.

Schedule II Consolidated Val300

Schedule II Consolidated Valuation and Qualifying Accounts - MEC (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2015
Allowance for Doubtful Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year		$ 37	$ 33	$ 22
Valuation Allowances and Reserves, Charged to Cost and Expense		33	37	23
Valuation Allowances and Reserves, Deductions		(39)	(33)	(21)
Valuation Allowances and Reserves, Balance		37	33	22	$ 31
Reserves not deducted from assets [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year	[1]	11	9	9
Valuation Allowances and Reserves, Charged to Cost and Expense	[1]	7	12	6
Valuation Allowances and Reserves, Deductions	[1]	(5)	(10)	(6)
Valuation Allowances and Reserves, Balance	[1]	11	9	9	13
MidAmerican Energy Company [Member] | Allowance for Doubtful Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year		7	10	10
Valuation Allowances and Reserves, Charged to Cost and Expense		7	7	7
Valuation Allowances and Reserves, Deductions		(8)	(10)	(7)
Valuation Allowances and Reserves, Balance		7	10	10	6
MidAmerican Energy Company [Member] | Reserves not deducted from assets [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year		11	9	9
Valuation Allowances and Reserves, Charged to Cost and Expense		7	12	6
Valuation Allowances and Reserves, Deductions		(5)	(10)	(6)
Valuation Allowances and Reserves, Balance		$ 11	$ 9	$ 9	$ 13
[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.

Schedule II Consolidated Val301

Schedule II Consolidated Valuation and Qualifying Accounts Schedule II Consolidated Valuation and Qualifying Accounts - LLC - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Allowance for Doubtful Accounts [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Balance		$ 31	$ 37	$ 33	$ 22
Valuation Allowances and Reserves, Charged to Cost and Expense		33	37	23
Valuation Allowances and Reserves, Deductions		39	33	21
Reserves not deducted from assets [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Balance	[1]	13	11	9	9
Valuation Allowances and Reserves, Charged to Cost and Expense	[1]	7	12	6
Valuation Allowances and Reserves, Deductions	[1]	5	10	6
MidAmerican Funding, LLC and Subsidiaries [Domain] | Allowance for Doubtful Accounts [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Balance		6	7	10	10
Valuation Allowances and Reserves, Charged to Cost and Expense		7	7	7
Valuation Allowances and Reserves, Deductions		8	10	7
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	11	9	$ 9
Valuation Allowances and Reserves, Charged to Cost and Expense		7	12	6
Valuation Allowances and Reserves, Deductions		$ 5	$ 10	$ 6
[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.