Puget Energy (PSD) 10-K 14 Mar 14 2013 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jun. 30, 2013
Entity Information [Line Items]	'	'
Entity Registrant Name	'PUGET ENERGY INC /WA	'
Entity Central Index Key	'0001085392	'
Current Fiscal Year End Date	'--12-31	'
Entity Well-known Seasoned Issuer	'No	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Non-accelerated Filer	'
Entity Public Float	'	$0
Entity Common Stock, Shares Outstanding	200	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'FY	'
Document Type	'10-K	'
Amendment Flag	'false	'
Document Period End Date	31-Dec-13	'
PUGET SOUND ENERGY, INC.	'	'
Entity Information [Line Items]	'	'
Entity Registrant Name	'PUGET SOUND ENERGY INC	'
Entity Central Index Key	'0000081100	'
Current Fiscal Year End Date	'--12-31	'
Entity Well-known Seasoned Issuer	'No	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Non-accelerated Filer	'
Entity Public Float	'	$0
Entity Common Stock, Shares Outstanding	85,903,791	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'FY	'
Document Type	'10-K	'
Amendment Flag	'false	'
Document Period End Date	31-Dec-13	'

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating revenue:	'	'	'
Electric	$2,156,920	$2,128,230	$2,147,220
Gas	1,028,357	1,086,095	1,168,850
Other	2,020	831	2,695
Total operating revenue	3,187,297	3,215,156	3,318,765
Energy costs:	'	'	'
Purchased electricity	541,905	622,288	771,405
Electric generation fuel	261,332	204,956	199,471
Residential exchange	-81,053	-73,555	-71,147
Purchased gas	488,201	538,612	622,088
Unrealized (gain) loss on derivative instruments, net	-102,744	-133,606	11,494
Utility operations and maintenance	529,939	512,765	497,921
Non-utility expense and other	-3,555	814	9,442
Depreciation	364,324	337,952	299,597
Amortization	24,631	55,819	72,381
Conservation Amortization	105,897	114,177	107,646
Taxes other than income taxes	303,260	319,399	323,527
Total operating expenses	2,432,137	2,499,621	2,843,825
Operating income (loss)	755,160	715,535	474,940
Other income (deductions):	'	'	'
Other income	38,693	49,069	58,052
Other expense	-7,134	-11,770	-5,380
Non-hedged interest rate swap expense	2,420	-4,288	-28,601
Interest charges:	'	'	'
AFUDC	11,261	22,216	29,949
Interest expense	-392,264	-392,216	-371,910
Income (loss) before income taxes	408,136	378,546	157,050
Income tax (benefit) expense	122,408	104,725	33,760
Net income (loss)	285,728	273,821	123,290
PUGET SOUND ENERGY, INC.	'	'	'
Operating revenue:	'	'	'
Electric	2,156,920	2,128,230	2,147,220
Gas	1,028,357	1,086,095	1,168,850
Other	2,058	1,934	3,733
Total operating revenue	3,187,335	3,216,259	3,319,803
Energy costs:	'	'	'
Purchased electricity	541,905	622,288	771,983
Electric generation fuel	261,332	204,956	199,471
Residential exchange	-81,053	-73,555	-71,147
Purchased gas	488,201	538,612	622,088
Unrealized (gain) loss on derivative instruments, net	-98,880	-119,120	54,146
Utility operations and maintenance	529,939	512,765	497,921
Non-utility expense and other	12,205	9,977	11,147
Depreciation	364,324	337,952	299,597
Amortization	24,631	55,819	72,381
Conservation Amortization	105,897	114,177	107,646
Taxes other than income taxes	303,260	319,399	323,527
Total operating expenses	2,451,761	2,523,270	2,888,760
Operating income (loss)	735,574	692,989	431,043
Other income (deductions):	'	'	'
Other income	38,690	49,056	58,041
Other expense	-7,134	-11,770	-5,380
Interest charges:	'	'	'
AFUDC	11,261	22,216	29,949
Interest expense	-261,264	-246,811	-231,212
Interest expense on parent note	-112	-202	-204
Income (loss) before income taxes	517,015	505,478	282,237
Income tax (benefit) expense	160,886	149,308	78,117
Net income (loss)	$356,129	$356,170	$204,120

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Parent [Line Items]	'	'	'
Net income (loss)	$285,728	$273,821	$123,290
Other comprehensive income (loss):	'	'	'
Other Comprehensive Income Reclassification Of Net Unrealized Gain Loss On Interest Rate Swaps During Period Net Of Tax	2,928	11,577	25,443
Net unrealized gain (loss) from pension and postretirement plans, net of tax	77,579	-13,870	-54,826
Reclassification of net unrealized loss on energy derivative instruments settled during the period, net of tax	37	371	1,545
Other comprehensive income (loss)	80,544	-1,922	-27,838
Comprehensive income (loss)	366,272	271,899	95,452
PUGET SOUND ENERGY, INC.	'	'	'
Parent [Line Items]	'	'	'
Net income (loss)	356,129	356,170	204,120
Other comprehensive income (loss):	'	'	'
Net unrealized gain (loss) from pension and postretirement plans, net of tax	88,593	-7,294	-52,927
Reclassification of net unrealized loss on energy derivative instruments settled during the period, net of tax	2,549	8,358	21,678
Amortization of treasury interest rate swaps to earnings, net of tax	317	317	317
Other comprehensive income (loss)	91,459	1,381	-30,932
Comprehensive income (loss)	$447,588	$357,551	$173,188

CONSOLIDATED_STATEMENTS_OF_COM1

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other comprehensive income (loss):	'	'	'
Net tax on reclassification of net unrealized loss on interest rate swaps during the period, tax	$1,577	$6,234	$13,700
Net unrealized gain (loss) from pension and postretirement plans, tax	41,773	-7,469	-29,522
Reclassification of net unrealized loss on energy derivative instruments during the period, tax	20	200	832
PUGET SOUND ENERGY, INC.	'	'	'
Other comprehensive income (loss):	'	'	'
Net unrealized gain (loss) from pension and postretirement plans, tax	47,705	-3,911	-28,474
Reclassification of net unrealized loss on energy derivative instruments during the period, tax	1,373	4,500	11,673
Amortization of treasury interest rate swaps to earnings, tax	$171	$171	$171

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
Utility Plant [Abstract]	'	'
Electric plant	$7,019,853,000	$6,750,400,000
Gas plant	2,528,629,000	2,385,784,000
Common plant	504,036,000	487,931,000
Less: Accumulated depreciation and amortization	-1,373,178,000	-1,067,424,000
Net utility plant	8,679,340,000	8,556,691,000
Other property and investments:	'	'
Goodwill	1,656,513,000	1,656,513,000
Other property and investments	100,332,000	112,367,000
Total other property and investments	1,756,845,000	1,768,880,000
Current assets:	'	'
Cash and cash equivalents	44,302,000	135,542,000
Restricted cash	7,171,000	3,700,000
Accounts receivable, net of allowance for doubtful accounts	408,512,000	321,480,000
Unbilled revenue	219,884,000	204,359,000
Materials and supplies, at average cost	88,140,000	82,353,000
Fuel and gas inventory, at average cost	66,717,000	88,953,000
Unrealized gain on derivative instruments	18,867,000	6,869,000
Taxes	297,000	4,796,000
Prepaid expense and other	18,787,000	13,571,000
Power contract acquisition adjustment gain	48,509,000	50,785,000
Deferred income taxes	86,004,000	53,437,000
Total current assets	1,007,190,000	965,845,000
Other long-term and regulatory assets:	'	'
Regulatory asset for deferred income taxes	146,867,000	119,844,000
Power cost adjustment mechanism	0	3,773,000
Regulatory assets related to power contracts	33,753,000	37,655,000
Other regulatory assets	749,382,000	815,785,000
Unrealized gain on derivative instruments	7,733,000	14,814,000
Power contract acquisition adjustment gain	394,556,000	456,225,000
Other	130,909,000	95,763,000
Total other long-term and regulatory assets	1,463,200,000	1,543,859,000
Total assets	12,906,575,000	12,835,275,000
Common shareholder’s equity:	'	'
Common stock	0	0
Additional paid-in capital	3,308,957,000	3,308,957,000
Earnings reinvested in the business	323,007,000	208,100,000
Accumulated other comprehensive income (loss), net of tax	47,715,000	-32,829,000
Total common shareholder’s equity	3,679,679,000	3,484,228,000
Long-term debt:	'	'
First mortgage bonds and senior notes	3,351,412,000	3,351,412,000
Pollution control bonds	161,860,000	161,860,000
Junior subordinated notes	250,000,000	250,000,000
Long-term debt	1,699,000,000	1,834,000,000
Debt discount and other	-229,796,000	-264,072,000
Total long-term debt	5,232,476,000	5,333,200,000
Total capitalization	8,912,155,000	8,817,428,000
Current liabilities:	'	'
Accounts payable	296,681,000	321,960,000
Short-term debt	162,000,000	181,000,000
Current maturities of long-term debt	0	13,000,000
Purchased gas adjustment liability	5,938,000	32,587,000
Accrued expenses:	'	'
Taxes	109,559,000	95,623,000
Salaries and wages	38,491,000	38,438,000
Interest	79,303,000	82,262,000
Unrealized loss on derivative instruments	48,049,000	177,519,000
Power contract acquisition adjustment loss	3,937,000	3,902,000
Other	60,335,000	72,594,000
Total current liabilities	804,293,000	1,018,885,000
Other Long-term and regulatory liabilities:	'	'
Deferred income taxes	1,487,005,000	1,261,636,000
Unrealized loss on derivative instruments	38,162,000	83,276,000
Power Cost Adjustment Mechanism Liability, Noncurrent	5,345,000	0
Regulatory liabilities	689,060,000	600,697,000
Regulatory liabilities related to power contracts	443,065,000	507,009,000
Power contract acquisition adjustment loss	29,816,000	33,753,000
Other deferred credits	497,674,000	512,591,000
Total other long-term and regulatory liabilities	3,190,127,000	2,998,962,000
Commitments and contingencies (Note 15)	'	'
Total capitalization and liabilities	12,906,575,000	12,835,275,000
PUGET SOUND ENERGY, INC.	'	'
Utility Plant [Abstract]	'	'
Electric plant	9,276,400,000	9,048,356,000
Gas plant	3,134,880,000	2,998,188,000
Common plant	565,072,000	555,549,000
Less: Accumulated depreciation and amortization	-4,297,012,000	-4,045,402,000
Net utility plant	8,679,340,000	8,556,691,000
Other property and investments:	'	'
Other property and investments	91,919,000	103,646,000
Total other property and investments	91,919,000	103,646,000
Current assets:	'	'
Cash and cash equivalents	44,111,000	135,530,000
Restricted cash	7,171,000	3,700,000
Accounts receivable, net of allowance for doubtful accounts	408,827,000	321,685,000
Unbilled revenue	219,884,000	204,359,000
Materials and supplies, at average cost	88,140,000	82,353,000
Fuel and gas inventory, at average cost	63,914,000	85,547,000
Unrealized gain on derivative instruments	18,867,000	6,869,000
Taxes	297,000	4,796,000
Prepaid expense and other	18,770,000	13,413,000
Deferred income taxes	141,058,000	68,015,000
Total current assets	1,011,039,000	926,267,000
Other long-term and regulatory assets:	'	'
Regulatory asset for deferred income taxes	146,350,000	119,279,000
Power cost adjustment mechanism	0	3,773,000
Other regulatory assets	749,382,000	813,171,000
Unrealized gain on derivative instruments	7,733,000	14,814,000
Other	123,125,000	90,330,000
Total other long-term and regulatory assets	1,026,590,000	1,041,367,000
Total assets	10,808,888,000	10,627,971,000
Common shareholder’s equity:	'	'
Common stock	859,000	859,000
Additional paid-in capital	3,246,205,000	3,246,205,000
Earnings reinvested in the business	289,432,000	344,280,000
Accumulated other comprehensive income (loss), net of tax	-95,739,000	-187,198,000
Total common shareholder’s equity	3,440,757,000	3,404,146,000
Long-term debt:	'	'
First mortgage bonds and senior notes	3,351,412,000	3,351,412,000
Pollution control bonds	161,860,000	161,860,000
Junior subordinated notes	250,000,000	250,000,000
Debt discount and other	-14,000	-14,000
Total long-term debt	3,763,258,000	3,763,258,000
Total capitalization	7,204,015,000	7,167,404,000
Current liabilities:	'	'
Accounts payable	296,675,000	321,952,000
Short-term debt	162,000,000	181,000,000
Short-term note owed to parent	29,598,000	29,598,000
Current maturities of long-term debt	0	13,000,000
Purchased gas adjustment liability	5,938,000	32,587,000
Accrued expenses:	'	'
Taxes	109,559,000	95,623,000
Salaries and wages	38,491,000	38,438,000
Interest	55,262,000	55,806,000
Unrealized loss on derivative instruments	41,465,000	170,948,000
Other	60,334,000	69,882,000
Total current liabilities	799,322,000	1,008,834,000
Other Long-term and regulatory liabilities:	'	'
Deferred income taxes	1,584,850,000	1,274,602,000
Unrealized loss on derivative instruments	31,523,000	68,323,000
Power Cost Adjustment Mechanism Liability, Noncurrent	5,345,000	0
Regulatory liabilities	686,176,000	596,324,000
Other deferred credits	497,657,000	512,484,000
Total other long-term and regulatory liabilities	2,805,551,000	2,451,733,000
Commitments and contingencies (Note 15)	'	'
Total capitalization and liabilities	$10,808,888,000	$10,627,971,000

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, except Share data, unless otherwise specified
Assets:	'	'
Construction work in progress	$310,318	$766,035
Current assets:	'	'
Allowance for doubtful accounts	7,385	9,932
Common shareholder’s equity:	'	'
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares authorized (in shares)	1,000	1,000
Common stock, shares outstanding (in shares)	200	200
PUGET SOUND ENERGY, INC.	'	'
Assets:	'	'
Construction work in progress	310,318	766,035
Current assets:	'	'
Allowance for doubtful accounts	$7,385	$9,932
Common shareholder’s equity:	'	'
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares authorized (in shares)	150,000,000	150,000,000,000
Common stock, shares outstanding (in shares)	85,903,791	85,903,791,000

CONSOLIDATED_STATEMENTS_OF_COM2

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER'S EQUITY (USD $)	Total	Common Stock	Additional Paid-in Capital	Earnings Reinvested in the Business	Accumulated Other Comprehensive Income (Loss)	PUGET SOUND ENERGY, INC.	PUGET SOUND ENERGY, INC.	PUGET SOUND ENERGY, INC.	PUGET SOUND ENERGY, INC.	PUGET SOUND ENERGY, INC.
In Thousands, except Share data, unless otherwise specified							Common Stock	Additional Paid-in Capital	Earnings Reinvested in the Business	Accumulated Other Comprehensive Income (Loss)
Balance at Dec. 31, 2010	$3,322,912	'	'	'	'	$2,974,907	'	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'	'	'
Net income (loss)	88,480	'	'	'	'	112,716	'	'	'	'
Balance at Mar. 31, 2011	'	'	'	'	'	'	'	'	'	'
Balance at Dec. 31, 2010	3,322,912	0	3,308,957	17,024	-3,069	2,974,907	859	2,959,205	172,490	-157,647
Balance (in shares) at Dec. 31, 2010	'	200	'	'	'	'	85,903,791	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'	'	'
Net income (loss)	123,290	0	0	123,290	0	204,120	0	0	204,120	0
Capital Contribution	'	'	'	'	'	287,000	0	287,000	0	0
Common stock dividend	-117,441	0	0	-117,441	0	-212,875	0	0	-212,875	0
Other comprehensive income	-27,838	0	0	0	-27,838	-30,932	0	0	0	-30,932
Balance at Dec. 31, 2011	3,300,923	0	3,308,957	22,873	-30,907	3,222,220	859	3,246,205	163,735	-188,579
Balance (in shares) at Dec. 31, 2011	'	200	'	'	'	'	85,903,791	'	'	'
Balance at Sep. 30, 2011	'	'	'	'	'	'	'	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'	'	'
Net income (loss)	80,957	'	'	'	'	95,714	'	'	'	'
Balance at Dec. 31, 2011	3,300,923	'	'	'	'	3,222,220	'	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'	'	'
Net income (loss)	167,475	'	'	'	'	179,938	'	'	'	'
Balance at Mar. 31, 2012	'	'	'	'	'	'	'	'	'	'
Balance at Dec. 31, 2011	3,300,923	0	3,308,957	22,873	-30,907	3,222,220	859	3,246,205	163,735	-188,579
Balance (in shares) at Dec. 31, 2011	'	200	'	'	'	'	85,903,791	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'	'	'
Net income (loss)	273,821	0	0	273,821	0	356,170	0	0	356,170	0
Common stock dividend	-88,594	0	0	-88,594	0	-175,625	0	0	-175,625	0
Other comprehensive income	-1,922	0	0	0	-1,922	1,381	0	'	0	1,381
Balance at Dec. 31, 2012	3,484,228	0	'	208,100	-32,829	3,404,146	859	3,246,205	344,280	-187,198
Balance (in shares) at Dec. 31, 2012	200	200	'	'	'	85,903,791,000	85,903,791	'	'	'
Balance at Sep. 30, 2012	'	'	'	'	'	'	'	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'	'	'
Net income (loss)	108,808	'	'	'	'	122,923	'	'	'	'
Balance at Dec. 31, 2012	3,484,228	0	'	208,100	-32,829	3,404,146	859	3,246,205	344,280	-187,198
Balance (in shares) at Dec. 31, 2012	200	200	'	'	'	85,903,791,000	85,903,791	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'	'	'
Net income (loss)	285,728	0	0	285,728	0	356,129	0	0	356,129	0
Common stock dividend	-170,821	0	0	-170,821	0	-410,977	0	0	-410,977	0
Other comprehensive income	80,544	0	0	0	80,544	91,459	0	0	0	91,459
Balance at Dec. 31, 2013	$3,679,679	$0	$3,308,957	$323,007	$47,715	$3,440,757	$859	$3,246,205	$289,432	($95,739)
Balance (in shares) at Dec. 31, 2013	200	200	'	'	'	85,903,791	85,903,791	'	'	'

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating activities:	'	'	'
Net income (loss)	$285,728	$273,821	$123,290
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'	'
Depreciation	364,324	337,952	299,597
Amortization	24,631	55,819	72,381
Conservation amortization	105,897	114,177	107,646
Deferred income taxes and tax credits, net	122,409	100,457	31,774
Net unrealized (gain) loss on derivative instruments	-106,540	-146,680	45,043
Derivative contracts classified as financing activities due to merger	34,250	92,681	182,710
AFUDC - equity	-15,930	-25,469	-32,431
Funding of pension liability	-20,400	-22,800	-5,000
Regulatory assets	-122,549	-170,374	-64,173
Regulatory liabilities	50,025	14,054	21,031
Other long-term assets	-24,877	-1,644	-61,734
Other long-term liabilities	180,015	95,166	46,473
Change in certain current assets and liabilities:	'	'	'
Accounts receivable and unbilled revenue	-103,949	35,537	-5,977
Materials and supplies	-5,787	-6,284	8,154
Fuel and gas inventory	21,633	11,527	-4,852
Taxes	4,499	6,174	65,213
Prepayments and other	-5,357	393	605
Purchased gas adjustment	-26,649	6,647	31,932
Accounts payable	4,597	-25,963	1,098
Taxes payable	13,936	4,896	9,222
Accrued expenses and other	-13,838	32,598	43,921
Net cash provided by operating activities	766,068	782,685	915,923
Investing activities:	'	'	'
Construction expenditures - excluding equity AFUDC	-567,938	-859,791	-976,513
Proceeds from disposition of assets	108,362	0	0
Treasury grant payment received	0	205,261	0
Restricted cash	-3,471	483	1,287
Other	-17,871	-38,923	-7,184
Net cash used in investing activities	-480,918	-692,970	-982,410
Financing activities:	'	'	'
Change in short-term debt and leases, net	-26,578	148,437	-227,651
Dividends paid	-170,821	-88,594	-117,441
Long-term notes and bonds issued	161,860	1,314,000	1,382,000
Redemption of bonds and notes	-309,860	-1,273,000	-769,000
Derivative contracts classified as financing activities due to merger	-34,250	-92,681	-182,710
Issuance cost of bonds and other	3,259	430	-18,033
Net cash provided by (used in) financing activities	-376,390	8,592	67,165
Net increase (decrease) in cash and cash equivalents	-91,240	98,307	678
Cash and cash equivalents at beginning of period	135,542	37,235	36,557
Cash and cash equivalents at end of period	44,302	135,542	37,235
Supplemental cash flow information:	'	'	'
Cash payments for interest (net of capitalized interest)	334,041	318,305	280,847
Income Taxes Paid, Net	-4,500	-1,898	-64,016
PUGET SOUND ENERGY, INC.	'	'	'
Operating activities:	'	'	'
Net income (loss)	356,129	356,170	204,120
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'	'
Depreciation	364,324	337,952	299,597
Amortization	24,631	55,819	72,381
Conservation amortization	105,897	114,177	107,646
Deferred income taxes and tax credits, net	160,886	145,040	77,174
Net unrealized (gain) loss on derivative instruments	-98,880	-119,120	54,146
AFUDC - equity	-15,930	-25,469	-32,431
Funding of pension liability	-20,400	-22,800	-5,000
Regulatory assets	-122,549	-170,374	-65,134
Regulatory liabilities	50,025	14,054	21,031
Other long-term assets	-21,932	932	-62,682
Other long-term liabilities	160,596	79,789	28,814
Change in certain current assets and liabilities:	'	'	'
Accounts receivable and unbilled revenue	-104,059	35,285	-6,204
Materials and supplies	-5,787	-6,284	8,154
Fuel and gas inventory	21,633	11,527	-4,852
Taxes	4,499	6,174	51,144
Prepayments and other	-5,357	393	605
Purchased gas adjustment	-26,649	6,647	31,932
Accounts payable	4,597	-25,972	688
Taxes payable	13,936	4,896	9,222
Accrued expenses and other	-9,931	-954	18,666
Net cash provided by operating activities	835,679	797,882	809,017
Investing activities:	'	'	'
Construction expenditures - excluding equity AFUDC	-567,938	-859,791	-976,513
Proceeds from disposition of assets	108,362	0	0
Treasury grant payment received	0	205,261	0
Restricted cash	-3,471	483	1,287
Other	-16,751	-18,022	9,043
Net cash used in investing activities	-479,798	-672,069	-966,183
Financing activities:	'	'	'
Change in short-term debt and leases, net	-26,578	148,437	-227,651
Dividends paid	-410,977	-175,625	-212,875
Long-term notes and bonds issued	161,860	0	595,000
Loan from (payment to) parent	0	-400	7,400
Redemption of bonds and notes	-174,860	0	-285,000
Investment from parent	0	0	287,000
Issuance cost of bonds and other	3,255	6,295	-12,018
Net cash provided by (used in) financing activities	-447,300	-21,293	151,856
Net increase (decrease) in cash and cash equivalents	-91,419	104,520	-5,310
Cash and cash equivalents at beginning of period	135,530	31,010	36,320
Cash and cash equivalents at end of period	44,111	135,530	31,010
Supplemental cash flow information:	'	'	'
Cash payments for interest (net of capitalized interest)	244,887	216,128	191,666
Income Taxes Paid, Net	($4,500)	($1,898)	($50,022)

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	Summary of Significant Accounting Policies
	Basis of Presentation
	Puget Energy, Inc. (Puget Energy) is an energy services holding company that owns Puget Sound Energy, Inc. (PSE).  PSE is a public utility incorporated in the state of Washington that furnishes electric and natural gas services in a territory covering 6,000 square miles, primarily in the Puget Sound region.  On February 6, 2009, Puget Holdings LLC (Puget Holdings), owned by a consortium of long-term infrastructure investors, completed its merger with Puget Energy (the merger).  As a result of the merger, all of Puget Energy’s common stock is indirectly owned by Puget Holdings.  The acquisition of Puget Energy was accounted for in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 805, “Business Combinations” (ASC 805), as of the date of the merger.  ASC 805 requires the acquirer to recognize and measure identifiable assets acquired and liabilities assumed at fair value as of the merger date.
	The consolidated financial statements of Puget Energy reflect the accounts of Puget Energy and its subsidiary, PSE.  PSE’s consolidated financial statements include the accounts of PSE and its subsidiary.  Puget Energy and PSE are collectively referred to herein as “the Company.”  The consolidated financial statements are presented after elimination of all significant intercompany items and transactions.  PSE’s consolidated financial statements continue to be accounted for on a historical basis and PSE’s financial statements do not include any ASC 805 purchase accounting adjustments.  The preparation of financial statements in conformity with U.S. Generally Accepted Accounting Principles (GAAP) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period.  Actual results could differ from those estimates.
	Certain prior year amounts have been corrected to conform to the current year presentation. In addition, at December 31, 2013, PSE revised 2012 credit balances in customer’s accounts receivable to accounts payable in the amount of $33.7 million in order to correct errors included in the December 31, 2012 balances. The Company believes these amounts are not material to the financial statements.
	Utility Plant
	Puget Energy and PSE capitalize, at original cost, additions to utility plant, including renewals and betterments.  Costs include indirect costs such as engineering, supervision, certain taxes, pension and other employee benefits and an Allowance For Funds Used During Construction (AFUDC).  Replacements of minor items of property are included in maintenance expense. When the utility plant is retired and removed from service, the original cost of the property is charged to accumulated depreciation and costs associated with removal of the property, less salvage, are charged to the cost of removal regulatory liability.
	Planned Major Maintenance
	Planned major maintenance is an activity that typically occurs when PSE overhauls or substantially upgrades various systems and equipment on its natural gas fired combustion turbines on a scheduled basis. Costs related to planned major maintenance, in excess of $0.5 million, are deferred and amortized to the next scheduled major maintenance. This accounting method also follows the Washington Utilities and Transportation Commission (Washington Commission) regulatory treatment related to these generating facilities.
	Non-Utility Property, Plant and Equipment
	For PSE, the costs of other property, plant and equipment are stated at historical cost.  Expenditures for refurbishment and improvements that significantly add to productive capacity or extend useful life of an asset are capitalized.  Replacement of minor items are expensed on a current basis.  Gains and losses on assets sold or retired are reflected in earnings.
	Depreciation and Amortization
	For financial statement purposes, the Company provides for depreciation and amortization on a straight-line basis.  Amortization is recorded for intangibles such as regulatory assets and liabilities, computer software and franchises.  The depreciation of vehicles and equipment is allocated to the asset and expense accounts based on usage.  The annual depreciation provision stated as a percent of a depreciable electric utility plant was 2.8%, 2.9% and 2.7% in 2013, 2012 and 2011, respectively; depreciable gas utility plant was 3.4%, 3.4% and 3.5% in 2013, 2012 and 2011, respectively; and depreciable common utility plant was 11.4%, 11.6% and 11.3% in 2013, 2012 and 2011, respectively.  Depreciation on other property, plant and equipment is calculated primarily on a straight-line basis over the useful lives of the assets.  The cost of removal is collected from PSE’s customers through depreciation expense and any excess is recorded as a regulatory liability.
	Goodwill
	On February 6, 2009, Puget Holdings completed its merger with Puget Energy.  Puget Energy remeasured the carrying amount of all its assets and liabilities to fair value, which resulted in recognition of approximately $1.7 billion in goodwill.  ASC 350, “Intangibles - Goodwill and Other” (ASC 350), requires that goodwill be tested for impairment at the reporting unit level on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value.  These events or circumstances could include a significant change in the Company’s business or regulatory outlook, legal factors, a sale or disposition of a significant portion of a reporting unit or significant changes in the financial markets which could influence the Company’s access to capital and interest rates.  Application of the goodwill impairment test requires judgment, including the identification of reporting units, assignment of assets and liabilities to reporting units, assignment of goodwill to reporting units and the determination of the fair value of the reporting units.  Management has determined Puget Energy has only one reporting unit.
	The goodwill recorded by Puget Energy represents the potential long-term return to the Company’s investors.  Goodwill is tested for impairment annually using a two-step process.  The first step compares the carrying amount of the reporting unit with its fair value, with a carrying value higher than fair value indicating potential impairment.  If the first step test fails, the second step is performed.  This would entail a full valuation of Puget Energy’s assets and liabilities and comparing the valuation to its carrying amounts, with the aggregate difference indicating the amount of impairment.  Goodwill of a reporting unit is required to be tested for impairment on an interim basis if an event occurs or circumstances change that would cause the fair value of a reporting unit to fall below its carrying amount.
	Puget Energy conducted its annual impairment test in 2013 using an October 1, 2013 measurement date.  The fair value of Puget Energy’s reporting unit was estimated using both discounted cash flow and market approach.  Such approaches are considered methodologies that market participants would use.  This analysis requires significant judgments, including estimation of future cash flows, which is dependent on internal forecasts, estimation of long-term rate of growth for Puget Energy business, estimation of the useful life over which cash flows will occur, the selection of utility holding companies determined to be comparable to Puget Energy and determination of an appropriate weighted-average cost of capital or discount rate.  The market approach estimates the fair value of the business based on market prices of stocks of comparable companies engaged in the same or similar lines of business.  In addition, indications of market value are estimated by deriving multiples of equity or invested capital to various measures of revenue, earnings or cash flow.  Changes in these estimates and or assumptions could materially affect the determination of fair value and goodwill impairment of the reporting unit.  Based on the test performed, management has determined that there was no indication of impairment of Puget Energy’s goodwill as of October 1, 2013.  There were no events or circumstances from the date of the assessment through December 31, 2013 that would impact management’s conclusion.
	Cash and Cash Equivalents
	Cash and cash equivalents consist of demand bank deposits and short-term highly liquid investments with original maturities of three months or less at the time of purchase.  The cash and cash equivalents balance at Puget Energy was $44.3 million and $135.5 million as of December 31, 2013 and 2012, respectively.  The 2013 and 2012 balance consisted of cash equivalents, which are reported at cost and approximate fair value, and were $2.6 million and $107.6 million, respectively.
	Materials and Supplies
	Materials and supplies are used primarily in the operation and maintenance of electric and natural gas distribution and transmission systems as well as spare parts for combustion turbines used for the generation of electricity.  Puget Energy and PSE record these items at weighted-average cost.
	Fuel and Gas Inventory
	Fuel and gas inventory is used in the generation of electricity and for future sales to the Company’s natural gas customers.  Fuel inventory consists of coal, diesel and natural gas used for generation.  Gas inventory consists of natural gas and liquefied natural gas (LNG) held in storage for future sales.  Puget Energy and PSE record these items at the lower of cost or market value using the weighted-average cost method.
	Regulatory Assets and Liabilities
	PSE accounts for its regulated operations in accordance with ASC 980 “Regulated Operations” (ASC 980).  ASC 980 requires PSE to defer certain costs that would otherwise be charged to expense, if it is probable that future rates will permit recovery of such costs.  It similarly requires deferral of revenues or gains and losses that are expected to be returned to customers in the future.  Accounting under ASC 980 is appropriate as long as rates are established by or subject to approval by independent third-party regulators; rates are designed to recover the specific enterprise’s cost of service; and in view of demand for service, it is reasonable to assume that rates set at levels that will recover costs can be charged to and collected from customers.  In most cases, PSE classifies regulatory assets and liabilities as long-term assets or liabilities due to the length of the amortization.  The exception is the Purchased Gas Adjustment (PGA) which can be a current asset or current liability.
	Allowance for Funds Used During Construction
	AFUDC represents the cost of both the debt and equity funds used to finance utility plant additions during the construction period.  The amount of AFUDC recorded in each accounting period varies depending principally upon the level of construction work in progress and the AFUDC rate used.  AFUDC is capitalized as a part of the cost of utility plant and is credited to interest expense and as a non-cash item to other income.  Cash inflow related to AFUDC does not occur until these charges are reflected in rates.
	The AFUDC rates authorized by the Washington Commission for natural gas and electric utility plant additions based on the effective dates are as follows:
	Effective Date	Washington Commission
		AFUDC Rates
	July 1, 2013 - present	7.77	%
	May 14, 2012 - June 30, 2013	7.8
	April 8, 2010 - May 13, 2012	8.1
	The Washington Commission authorized the Company to calculate AFUDC using its allowed rate of return.  To the extent amounts calculated using this rate exceed the AFUDC calculated rate using the Federal Energy Regulatory Commission (FERC) formula, PSE capitalizes the excess as a deferred asset, crediting other income.  The deferred asset is being amortized over the average useful life of PSE’s non-project electric utility plant which is approximately 30 years.
	Revenue Recognition
	Operating utility revenue is recognized when the basis of services is rendered, which includes estimated unbilled revenue, in accordance with ASC 605, “Revenue Recognition” (ASC 605).  PSE's estimate of unbilled revenue is based on a calculation using meter readings from its automated meter reading (AMR) system. The estimate calculates unbilled usage at the end of each month as the difference between the customer meter readings on the last day of the month and the last customer meter readings billed. The unbilled usage is then priced at published rates for each schedule to estimate the unbilled revenues by customer.
	Non-utility subsidiaries recognize revenue when services are performed or upon the sale of assets.  Revenue from retail sales is billed based on tariff rates approved by the Washington Commission.  Sales of Renewable Energy Credits (RECs) are deferred as a regulatory liability.
	PSE collected Washington State excise taxes (which are a component of general retail customer rates) and municipal taxes totaling $243.9 million, $244.2 million and $252.5 million for 2013, 2012 and 2011, respectively.  The Company reports the collection of such taxes on a gross basis in operating revenue and as expense in taxes other than income taxes in the accompanying consolidated statements of income.
	Beginning July 1, 2013, PSE's electric and gas operations contain a revenue decoupling mechanism under which PSE's actual energy delivery revenues related to electric transmission and distribution, gas operations and general administrative costs are compared with authorized revenues allowed under the mechanism. Any differences are deferred to a regulatory asset for under recovery or regulatory liability for over recovery. Revenues associated with power costs under the Power Cost Adjustment (PCA) mechanism and PGA rates are excluded from the decoupling mechanism.
	Allowance for Doubtful Accounts
	Allowance for doubtful accounts are provided for electric and natural gas customer accounts based upon a historical experience rate of write-offs of energy accounts receivable along with information on future economic outlook.  The allowance account is adjusted monthly for this experience rate.   The allowance account is maintained until either receipt of payment or the likelihood of collection is considered remote at which time the allowance account and corresponding receivable balance are written off.
	The Company’s allowance for doubtful accounts at December 31, 2013 and 2012 was $7.4 million and $9.9 million, respectively.
	Self-Insurance
	PSE currently has no insurance coverage for storm damage and recent environmental contamination occurring on PSE-owned property.  PSE is self-insured for a portion of the risk associated with comprehensive liability, workers’ compensation claims and catastrophic property losses other than those which are storm related.  The Washington Commission has approved the deferral of certain uninsured qualifying storm damage costs that exceed $8.0 million which will be requested for collection in future rates.  Additionally, costs may only be deferred if the outage meets the Institute of Electrical and Electronics Engineers (IEEE) outage criteria for system average interruption duration index.
	Federal Income Taxes
	For presentation in Puget Energy and PSE’s separate financial statements, income taxes are allocated to the subsidiaries on the basis of separate company computations of tax, modified by allocating certain consolidated group limitations which are attributed to the separate company.  Taxes payable or receivable are settled with Puget Holdings.
	Natural Gas Off-System Sales and Capacity Release
	PSE contracts for firm natural gas supplies and holds firm transportation and storage capacity sufficient to meet the expected peak winter demand for natural gas by its firm customers.  Due to the variability in weather, winter peaking consumption of natural gas by most of its customers and other factors, PSE holds contractual rights to natural gas supplies and transportation and storage capacity in excess of its average annual requirements to serve firm customers on its distribution system.  For much of the year, there is excess capacity available for third-party natural gas sales, exchanges and capacity releases.  PSE sells excess natural gas supplies, enters into natural gas supply exchanges with third parties outside of its distribution area and releases to third parties excess interstate natural gas pipeline capacity and natural gas storage rights on a short-term basis to mitigate the costs of firm transportation and storage capacity for its core natural gas customers.  The proceeds from such activities, net of transactional costs, are accounted for as reductions in the cost of purchased natural gas and passed on to customers through the PGA mechanism, with no direct impact on net income.  As a result, PSE nets the sales revenue and associated cost of sales for these transactions in purchased natural gas.
	Non-Core Gas Sales
	As part of the Company’s electric operations, PSE provides natural gas to its gas-fired generation facilities.  The projected volume of natural gas for power is relative to the price of natural gas.  Based on the market prices for natural gas, PSE may use the gas it has already purchased to generate power or PSE may sell the already purchased natural gas.  The net proceeds from selling natural gas, previously purchased for power generation, are accounted for in other electric operating revenue and are included in the PCA mechanism.
	Production Tax Credit
	Production Tax Credits (PTCs) represent federal income tax incentives available to taxpayers that generate energy from qualifying renewable sources.  Prior to July 1, 2010, PSE passed the benefit of the PTCs to customers as the benefits were generated.  After July 1, 2010, PSE records the benefit of the PTCs as a regulatory liability until such time as PSE utilizes the tax credit on its tax return. Once utilized, PSE will pass the benefit to customers.
	Accounting for Derivatives
	ASC 815 requires that all contracts considered to be derivative instruments be recorded on the balance sheet at their fair value unless the contracts qualify for an exception.  PSE enters into derivative contracts to manage its energy resource portfolio and interest rate exposure including forward physical and financial contracts and swaps.  Some of PSE’s physical electric supply contracts qualify for the Normal Purchase Normal Sale (NPNS) exception to derivative accounting rules.  PSE may enter into financial fixed price contracts to economically hedge the variability of certain index-based contracts.  Those contracts that do not meet the NPNS exception are marked-to-market to current earnings in the statements of income, subject to deferral under ASC 980, for energy related derivatives due to the PCA mechanism and PGA mechanism.
	Puget Energy and PSE elected to de-designate all energy related derivative contracts previously recorded as cash flow hedges for the purpose of simplifying its financial reporting in 2009.  The contracts that were de-designated related to physical electric supply contracts and natural gas swap contracts used to fix the price of natural gas for electric generation.  For these contracts and for contracts initiated after such date, all mark-to-market adjustments are recognized through earnings.  The amount previously recorded in accumulated other comprehensive income (OCI) is transferred to earnings in the same period or periods during which the hedged transaction affects earnings or sooner if management determines that the forecasted transaction is probable of not occurring.  As a result, the Company will continue to experience the earnings impact of these reversals from OCI in future periods.
	The Company may enter into swap instruments or other financial derivative instruments to manage the interest rate risk associated with its long-term debt financing and debt instruments.  As of December 31, 2013, Puget Energy has interest rate swap contracts outstanding related to its long-term debt.  For additional information, see Note 9 Accounting for Derivative Instruments and Hedging Activities.
	Fair Value Measurements of Derivatives
	ASC 820, “Fair Value Measurements and Disclosures” (ASC 820), defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price).  However, as permitted under ASC 820, the Company utilizes a mid-market pricing convention (the mid-point price between bid and ask prices) as a practical expedient for valuing the majority of its assets and liabilities measured and reported at fair value.  The Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique.  These inputs can be readily observable, market corroborated or generally unobservable.  The Company primarily applies the market approach for recurring fair value measurements as it believes that the approach is used by market participants for these types of assets and liabilities.  Accordingly, the Company utilizes valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.
	The Company values derivative instruments based on daily quoted prices from an independent external pricing service.  When external quoted market prices are not available for derivative contracts, the Company uses a valuation model that uses volatility assumptions relating to future energy prices based on specific energy markets and utilizes externally available forward market price curves.  All derivative instruments are sensitive to market price fluctuations that can occur on a daily basis.  For additional information, see Note 10 Fair Value Measurements.
	Debt Related Costs
	Debt premiums, discounts, expenses and amounts received or incurred to settle hedges are amortized over the life of the related debt for the Company.  The premiums and costs associated with reacquired debt are deferred and amortized over the life of the related new issuance, in accordance with ratemaking treatment for PSE.
	Statements of Cash Flows
	The Company has refinancing transactions that do not result in an actual exchange of cash. For these transactions, the Company evaluates if the non-exchange of cash is for convenience purposes and if so, the Company considers the transaction as if it had constructively received and disbursed the cash and presents the transaction as gross on the financing section of the statements of cash flows.
PSE funds cash dividends to pay the shareholder of Puget Energy.
The following non-cash investing and financing activities have occurred at the Company:
•	PSE did not incur any capital lease obligations in 2013 or 2012. PSE incurred capital lease obligations of $37.9 million for AMR modules and network in 2011.
The Company revised its Consolidated Statement of Cash Flows due to an immaterial error. Revisions were made in the second quarter ended June 30, 2013 on the Company's Consolidated Statement of Cash Flows to reflect energy efficiency expenditures as operating cash outflows instead of investing cash outflows. The Company determined energy efficiency expenditures should have been classified as operating activities instead of investing activities. These revisions decreased net cash provided by operating activities and decreased net cash used by investing activities. The revision does not affect the net change in cash and cash equivalents for any of the periods, and has no effect on the Company's Consolidated Statements of Income, Consolidated Statements of Comprehensive Income, Consolidated Balance Sheets, and Consolidated Statement of Common Shareholder's Equity. The Company has evaluated the effects of these errors and concluded that none of them are material to any of the Company's previously issued quarterly or annual Financial Statements. Nevertheless, the Company has elected to revise the Consolidated Statement of Cash Flows in this report to correct for the effect of these errors and properly reflect the revised values.
The amounts on prior period Consolidated Statements of Cash Flows that have been revised are summarized below:
	As Reported						As Revised
Puget Energy	Year Ended December 31,						Year Ended December 31,
(Dollars in Thousands)	2012			2011			2012			2011
Operating Activities:
Regulatory Assets	$	(64,368	)	$	30,232		$	(170,374	)	$	(64,173	)
Net Cash Provided by Operating Activities	$	888,691		$	1,010,328		$	782,685		$	915,923
Investing Activities:
Energy Efficiency Expenditures	$	(106,006	)	$	(94,405	)	$	—		$	—
Net Cash Used in Investing Activities	$	(798,976	)	$	(1,076,815	)	$	(692,970	)	$	(982,410	)
	As Reported						As Revised
Puget Sound Energy	Year Ended December 31,						Year Ended December 31,
(Dollars in Thousands)	2012			2011			2012			2011
Operating Activities:
Regulatory Assets	$	(64,368	)	$	29,271		$	(170,374	)	$	(65,134	)
Net Cash Provided by Operating Activities	$	903,888		$	903,422		$	797,882		$	809,017
Investing Activities:
Energy Efficiency Expenditures	$	(106,006	)	$	(94,405	)	$	—		$	—
Net Cash Used in Investing Activities	$	(778,075	)	$	(1,060,588	)	$	(672,069	)	$	(966,183	)
Accumulated Other Comprehensive Income (Loss)
The following tables set forth the components of the Company’s accumulated other comprehensive income (loss) at:
Puget Energy	December 31,
(Dollars in Thousands)	2013			2012
Net unrealized loss on energy derivative instruments	$	(705	)	$	(742	)
Net unrealized loss on interest rate swaps	(94		)	(3,022		)
Net unrealized loss and prior service cost on pension plans	48,514			(29,065		)
Total Puget Energy, net of tax	$	47,715		$	(32,829	)
Puget Sound Energy	December 31,
(Dollars in Thousands)	2013			2012
Net unrealized loss on energy derivative instruments	$	(2,027	)	$	(4,576	)
Net unrealized loss on treasury interest rate swaps	(6,307		)	(6,624		)
Net unrealized loss and prior service cost on pension plans	(87,405		)	(175,998		)
Total PSE, net of tax	$	(95,739	)	$	(187,198	)

New_Accounting_Pronouncements

New Accounting Pronouncements	12 Months Ended
	Dec. 31, 2013
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]	'
New Accounting Pronouncements	'
	New Accounting Pronouncements
	Balance Sheet
	In December 2011, the FASB issued ASU 2011-11, Balance Sheet (Topic 210) (ASU 2011-11). ASU 2011-11, as amended by ASU 2013-01, Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, enhances disclosure requirements about the nature of an entity's right to offset and related arrangements associated with its derivative instruments. ASU 2011-11 requires the disclosure of the gross amounts subject to rights of set-off, amounts offset in accordance with the accounting standards followed, and the related net exposure.
	ASU 2011-11, as amended, is effective for fiscal years, and interim periods within those years, beginning on or after January 1, 2013. Retrospective application of the disclosures is required for all periods presented within the financial statements.  These disclosure requirements are the only impact on the Company’s consolidated financial statements. The Company adopted the Accounting Standards Update (ASU) requirements as disclosed in Note 9 - Accounting for Derivative Instruments and Hedging Activities.
	Comprehensive Income
	In February 2013, the FASB issued ASU 2013-02, Comprehensive Income (Topic 220): Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (ASU 2013-02), to improve the transparency of reporting reclassifications out of accumulated other comprehensive income. ASU 2013-02 requires an entity to present (either on the face of the statement where net income is presented or in the notes) the effects on the line items of net income of significant amounts reclassified out of accumulated other comprehensive income but only if the item reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. ASU 2013-02 also requires an entity to cross-reference to other disclosures currently required under U.S. GAAP for other reclassification items (that are not required under U.S. GAAP) to be reclassified directly to net income in their entirety in the same reporting period. This would be the case when a portion of the amount reclassified out of accumulated other comprehensive income is initially transferred to a balance sheet account instead of directly to income or expense.
	ASU 2013-02 is effective for reporting periods beginning after December 15, 2012, for public companies and is effective for reporting periods beginning after December 15, 2013, for private companies. Other than additional disclosures or a change in the presentation on the statement of comprehensive income when necessary, ASU 2013-02 does not impact the Company's consolidated results of operations, cash flows or financial position. The Company adopted the ASU requirements as disclosed in Note 18 - Accumulated Other Comprehensive Income (Loss).

Regulation_and_Rates

Regulation and Rates	12 Months Ended
	Dec. 31, 2013
Regulated Operations [Abstract]	'
Regulation and Rates	'
	Regulation and Rates
	Regulatory Assets and Liabilities
	ASC 980 requires PSE to defer certain costs that would otherwise be charged to expense, if it is probable that future rates will permit recovery of such costs.  It similarly requires deferral of revenues or gains and losses that are expected to be returned to customers in the future.
	Below is a chart with the allowed return on the net regulatory assets and liabilities and the associated time periods:
	Period	Rate of Return	After-Tax Return
	July 1, 2013 - present	7.77%	6.69%
	May 14, 2012 - June 30, 2013	7.8	6.71
	April 8, 2010 - May 13, 2012	8.1	6.9
	The net regulatory assets and liabilities at December 31, 2013 and 2012 included the following:
	Puget Sound Energy	Remaining Amortization Period	December 31,
	(Dollars in Thousands)		2013			2012
	PGA deferral of unrealized losses on derivative instruments	(a)	$	27,555		$	95,953
	Chelan PUD contract initiation	17.8 years	126,404			133,492
	Storm damage costs electric	1 to 5 years	116,328			131,904
	Environmental remediation	(a)	57,342			66,402
	Baker Dam licensing operating and maintenance costs	45 years	57,270			57,644
	Snoqualmie licensing operating and maintenance costs	31 years	10,881			7,816
	Colstrip common property	10.5 years	7,479			8,195
	Deferred income taxes	(a)	146,350			119,279
	Deferred Washington Commission AFUDC	Varies up to 36 years	55,495			55,896
	Energy conservation costs	1 to 2 years	35,987			26,940
	Unamortized loss on reacquired debt	1 to 22.5 years	37,832			31,399
	White River relicensing and other costs	(a)	28,190			29,654
	Mint Farm ownership and operating costs	11.3 years	22,320			24,321
	Investment in Bonneville Exchange power contract	3.5 years	12,343			15,870
	Ferndale	5.8 years	22,811			1,789
	Lower Snake River	2.3 to 23.3 years	92,924			126,887
	Snoqualmie	5.8 years	8,009			—
	Property tax tracker	(a)	22,134			—
	Various other regulatory assets	Varies	8,078			2,782
	Total PSE regulatory assets		$	895,732		$	936,223
	Cost of removal	(b)	$	(269,536	)	$	(239,243	)
	Production tax credits	(c)	(93,618		)	(93,618		)
	PGA payable	1 year	(5,938		)	(32,587		)
	PCA mechanism	(a)	(5,345		)	—
	Decoupling over-collection	(a)	(20,535		)	—
	Summit purchase option buy-out	6.8 years	(10,763		)	(12,338		)
	Deferred gain on Jefferson County sale	(a)	(60,844		)	—
	Deferred credit on Biogas sale	1 year	(10,908		)	—
	Deferred credit on gas pipeline capacity	Varies up to 4.8 years	(4,508		)	(6,213		)
	Renewable energy credits	(a)	(5,820		)	(11,341		)
	Treasury grants	6 to 9 years	(203,889		)	(225,573		)
	Various other regulatory liabilities	Up to 4 years	(5,755		)	(7,998		)
	Total PSE regulatory liabilities		$	(697,459	)	$	(628,911	)
	PSE net regulatory assets (liabilities)		$	198,273		$	307,312
	_______________
	(a)	Amortization periods vary depending on timing of underlying transactions or awaiting regulatory approval in a future Washington Commission rate proceeding.
	(b)	The balance is dependent upon the cost of removal of underlying assets and the life of utility plant.
	(c)	Amortization will begin once PTCs are utilized by PSE on its tax return.
	Puget Energy	Remaining Amortization Period	December 31,
	(Dollars in Thousands)		2013			2012
	Total PSE regulatory assets	(a)	$	895,732		$	936,223
	Puget Energy acquisition adjustments:
	Regulatory assets related to power contracts	1 to 23 years	33,753			37,655
	Various other regulatory assets	Varies	517			3,179
	Total Puget Energy regulatory assets		$	930,002		$	977,057
	Total PSE regulatory liabilities	(a)	$	(697,459	)	$	(628,911	)
	Puget Energy acquisition adjustments:
	Regulatory liabilities related to power contracts	1 to 38 years	(443,065		)	(507,009		)
	Various other regulatory liabilities	Varies	(2,884		)	(4,373		)
	Total Puget Energy regulatory liabilities		$	(1,143,408	)	$	(1,140,293	)
	Puget Energy net regulatory asset (liabilities)		$	(213,406	)	$	(163,236	)
	_______________
(a)	Puget Energy’s regulatory assets and liabilities include purchase accounting adjustments under ASC 805 as a result of the merger.
If the Company determines that it no longer meets the criteria for continued application of ASC 980, the Company would be required to write off its regulatory assets and liabilities related to those operations not meeting ASC 980 requirements.  Discontinuation of ASC 980 could have a material impact on the Company’s financial statements.
In accordance with guidance provided by ASC 410, “Asset Retirement and Environmental Obligations,” PSE reclassified from accumulated depreciation to a regulatory liability $269.5 million and $239.2 million in 2013 and 2012, respectively, for the cost of removal of utility plant.  These amounts are collected from PSE’s customers through depreciation rates.
Electric Regulation and Rates
Storm Damage Deferral Accounting
The Washington Commission issued a general rate case order that defined deferrable catastrophic/extraordinary losses and provided that costs in excess of $8.0 million annually may be deferred for qualifying storm damage costs that meet the modified IEEE outage criteria for system average interruption duration index. In 2013 and 2012, PSE incurred $9.5 million and $71.5 million, respectively, in storm-related electric transmission and distribution system restoration costs, of which no amount was deferred in 2013 and $60.4 million was deferred in 2012.
Power Cost Only Rate Case
Power Cost Only Rate Case (PCORC), a limited-scope proceeding, was approved in 2002 by the Washington Commission to periodically reset power cost rates.  In addition to providing the opportunity to reset all power costs, the PCORC proceeding also provides for timely review of new resource acquisition costs and inclusion of such costs in rates at the time the new resource goes into service.  To achieve this objective, the Washington Commission has used an expedited six-month PCORC decision timeline rather than the statutory 11-month timeline for a general rate case.
On October 23, 2013, the Washington Commission approved an update on the Company's PCORC, effective November 1, 2013, which reflected decreases in the overall normalized power supply costs. This resulted in an estimated revenue decrease of $10.5 million or 0.5% annually.
Electric Rate Case
On June 25, 2013, the Washington Commission approved PSE's electric and natural gas decoupling mechanism and expedited rate filing (ERF) tariff filings, effective July 1, 2013. The estimated revenue impact of the decoupling mechanism for electric is an increase of $21.4 million, or 1.0% annually. The estimated revenue impact of the ERF filings for electric is an increase of $30.7 million, or 1.5% annually. In its order, the Washington Commission approved a weighted cost of capital of 7.77% and a capital structure that included 48.0% common equity with a return on equity of 9.8%. Subsequently, certain parties to this proceeding petitioned the Washington Commission to reconsider the order. On December 13, 2013, the Washington Commission approved the settlement agreements for rates effective January 1, 2014. These settlement agreements do not materially change the revenues originally approved in June 2013.
On July 24, 2013, the Public Counsel Division of the Washington State Attorney General's Office (Public Counsel) and the Industrial Customers of Northwest Utilities (ICNU) each filed a petition in Thurston County Superior Court (the Court) seeking judicial review of various aspects of the Washington Commission's ERF and decoupling mechanism final order. The parties' petition argues that the order violates various procedural and substantive requirements of the Washington Administrative Procedure Act, and so requests that it be vacated and that the matter be remanded to the Washington Commission. Oral arguments regarding this matter are scheduled for May 2014.
On May 7, 2012, the Washington Commission issued its order in PSE's electric general rate case filed in June 2011, approving a general rate increase for electric customers of $63.3 million or 3.2% annually. The rate increases for electric customers became effective May 14, 2012. In its order, the Washington Commission approved a weighted cost of capital of 7.8% and a capital structure that included 48.0% common equity with a return on equity of 9.8%. PSE's requested treatment of the prepayments made to Bonneville Power Administration (BPA), filed in May 2010, was approved in the order. The final order rejected PSE's proposed conservation savings adjustment. Finally, a new rate rider for RECs was proposed by settlement of electric parties and approved by the Washington Commission in the final order.
The following table sets forth electric rate adjustments approved by the Washington Commission and the corresponding impact on PSE’s revenue based on the effective dates:
Type of Rate	Effective Date	Average	Increase (Decrease)
Adjustment		Percentage	in Revenue
		Increase (Decrease)	(Dollars in Millions)
		in Rates
PCORC	1-Nov-13	-0.50%	($10.50)
Decoupling Rate Filing	1-Jul-13	1	21.4
Expedited Rate Filing	1-Jul-13	1.5	30.7
Electric General Rate Case	May 14, 2012, Annual	3.2	63.3
Renewable Energy Credit Proceeds	November 1, 2010 - March 31, 2011	-2.9	-27.7
In addition, PSE will be increasing the allowed delivery revenue per customer under the ERF filing by 3.0% for electric customers on January 1 of each year until the conclusion of PSE's next general rate case.
Accounting Orders and Petitions
On November 27, 2013, the Washington Commission issued an order authorizing PSE to provide the net proceeds from the sale of natural gas supply produced from a landfill-gas recovery project in King County (Biogas) prior to October 31, 2013 as a bill credit to customers over a one-year period in its Renewable Energy Credits adjusting price schedule which became effective January 1, 2014.  Additionally, the Washington Commission order authorized that all net proceeds from Biogas produced after October 31, 2013 plus the internal labor needed to obtain the net proceeds is reflected as a PSE below-the-line item (i.e., not included in the revenues and expenses considered when setting electric customer rates) and excluded from utility operations.
PSE completed the sale of its electric infrastructure assets located in Jefferson County and the transition of electrical services in the county to Jefferson County Public Utility District (JPUD) on March 31, 2013.  The proceeds from the sale exceeded the transferred assets' net carrying value of $46.7 million resulting in a pre-tax gain of approximately $60.0 million.  In its 2010 order on the subject, the Washington Commission stated that PSE must file an accounting and ratemaking petition with the Washington Commission to determine how this gain will be allocated between customers and shareholders.  As a result, the gain was deferred and recorded as a regulatory liability until the Washington Commission determines the accounting and ratemaking treatment.   On October 31, 2013, PSE filed an accounting petition for a Washington Commission order that authorizes PSE to retain the gain of $45.0 million and return $15.0 million to its remaining customers over a period of 48 months.  Intervenors testimony is scheduled to be filed in March, 2014. For federal income tax purposes, the Company will elect to treat the transaction as an involuntary conversion under the Internal Revenue Code which allows for deferral of the tax gain if PSE acquires qualified replacement property by December 31, 2015.  Based on PSE's current construction program projection, it anticipates meeting this requirement through such purchases by that date.
PCA Mechanism
In 2002, the Washington Commission approved a PCA mechanism that provides for a rate adjustment process if PSE’s costs to provide customers’ electricity vary from a baseline power cost rate established in a rate proceeding. All significant variable power supply cost variables (hydroelectric and wind generation, market price for purchased power and surplus power, natural gas and coal fuel price, generation unit forced outage risk and transmission cost) are included in the PCA mechanism.
The PCA mechanism apportions increases or decreases in power costs, on a calendar year basis, between PSE and its customers on a graduated scale.
The graduated scale is as follows:
Annual Power Cost Variability	Customers’ Share	Company’s Share
+/- $20 million	0%	100%
+/- $20 million - $40 million	50%	50%
+/- $40 million - $120 million	90%	10%
+/- $120 + million	95%	5%
Treasury Grant
Section 1603 of the American Recovery and Reinvestment Tax Act of 2009 (Section 1603) authorizes the United States Department of the Treasury (U.S. Treasury) to make grants (Treasury Grants) to taxpayers who place specified energy property in service provided certain conditions are met.   Section 1603 precludes a recipient from claiming PTCs on property for which a grant is claimed.
The Wild Horse wind project (Wild Horse) expansion facility was placed into service on November 9, 2009. The capacity of the Wild Horse facility was expanded from 229 megawatts (MW) to 273 MW through the addition of wind turbines.  In February 2010, the U.S. Treasury approved a Treasury Grant of $28.7 million. The 343 MW Lower Snake River facility was placed into service on February 29, 2012. In December 2012, the U.S. Treasury approved a Treasury Grant of $205.3 million.
On December 30, 2010, the Washington Commission approved revisions to PSE’s Federal Incentive Tracker tariff, effective January 1, 2011.  The rate schedule passed-through $5.5 million of the $28.7 million Wild Horse Expansion Treasury Grant in 2011.  The order authorized PSE to pass back one-tenth of the Treasury Grant on an annual basis and included 23 months of Treasury Grant amortization to customers from February 2010 through December 2011, which represented the month the Treasury Grant funds were received through the end of the period over which the rates will be set.  This represents an overall average rate reduction of 0.3%, with no impact to net income.
On February 29, 2012, PSE filed proposed tariff revisions, with stated effective dates of April 1, 2012, and subsequently revised by filing on March 29, 2012 with stated effective dates of June 1, 2012, to pass-through $2.4 million in interest on the unamortized balance of the Wild Horse Expansion Treasury Grant.  On June 26, 2012, the Washington Commission approved PSE's methods and calculations and new rates became effective on July 3, 2012.
On January 31, 2013, the Washington Commission approved a rate change to the PSE's Federal Incentive Tracker tariff, effective February 1, 2013, which incorporated the effects of the Treasury Grant related to the Lower Snake River wind generation project and keeping the ten year amortization period and inclusion of interest on the unamortized balance of the grants. The rate change passed through 11 months of amortization for both grants to eligible customers over 11 months beginning February 1, 2013. Of the total credit, $34.6 million represents the pass-back of grant amortization and $23.8 million represents the pass through of interest. This represents an overall average rate decrease of 2.76%.
On December 27, 2013, the Washington Commission approved the annual true-up and rate filing to the PSE's Federal Incentive Tracker tariff, effective January 1, 2014. The true-up filing resulted in a total credit of $58.5 million to be passed back to eligible customers over the twelve months beginning January 1, 2014.  Of the total credit, $37.8 million represents the pass-back of grant amortization and $20.6 million represents the pass through of interest, in addition to a minor true-up associated with the 2013 rate period.  This filing represents an overall average rate increase of 0.26%.
Gas Regulation and Rates
Gas General Rate Cases and Other Filings Affecting Rates
On May 7, 2012, the Washington Commission issued its order in PSE's natural gas general rate case filed in June 2011, approving a general rate increase for natural gas customers of $13.4 million or 1.3% annually. The rate increases for natural gas customers became effective May 14, 2012. In its order, the Washington Commission approved a weighted cost of capital of 7.8% and a capital structure that included 48.0% common equity with a return on equity of 9.8%.
On June 1, 2012, PSE filed with the Washington Commission a petition seeking an Accounting Order authorizing PSE to change the existing natural gas conservation tracker mechanism into a rider mechanism to be consistent with the electric conservation program recovery. The accounting petition requested the ability to recover the costs associated with the Company's current gas conservation programs via transfers from amounts deferred for the over-recovery of commodity costs in the Company's PGA mechanism. The Commission granted PSE's accounting petition on June 28, 2012. The approved accounting petition resulted in an increase to gas conservation revenues of $6.9 million and an increase to conservation amortization expense of $6.6 million.
On June 25, 2013, the Washington Commission approved PSE's electric and natural gas decoupling mechanism and ERF tariff filings, effective July 1, 2013. The estimated revenue impact of the decoupling mechanism for natural gas is an increase of $10.8 million, or 1.1% annually. The estimated revenue impact of the ERF filings for natural gas is a decrease of $2.0 million, or a decrease of 0.2% annually. In its order, the Washington Commission approved a weighted cost of capital of 7.77% and a capital structure that included 48.0% common equity with a return on equity of 9.8%.
Subsequently, certain parties to this proceeding petitioned the Washington Commission to reconsider the order. On December 13, 2013, the Washington Commission approved a series of settlement agreements for rates effective January 1, 2014. These settlement agreements do not materially change the revenues originally approved in June 2013. As a result, certain high volume natural gas industrial customers rate schedules are excluded from the decoupling mechanism and will be subject to certain effects of abnormal weather, conservation impacts and changes in customer usage patterns.
On July 24, 2013, the Public Counsel Division of the Washington State Attorney General's Office (Public Counsel) and the Industrial Customers of Northwest Utilities (ICNU) each filed a petition in Thurston County Superior Court (the Court) seeking judicial review of various aspects of the Washington Commission's ERF and decoupling mechanism final order. The parties' petition argues that the order violates various procedural and substantive requirements of the Washington Administrative Procedure Act, and so requests that it be vacated and that the matter be remanded to the Washington Commission. Oral arguments regarding this matter are scheduled for May 2014.
Purchased Gas Adjustment
PSE has a PGA mechanism in retail natural gas rates to recover variations in natural gas supply and transportation costs.  Variations in natural gas rates are passed through to customers; therefore, PSE’s net income is not affected by such variations.  Changes in the PGA rates affect PSE’s revenue, but do not impact net income as the changes to revenue are offset by increased or decreased purchased gas and gas transportation costs.
On October 31, 2012, the Washington Commission approved PSE's PGA natural gas tariff filing and allowed the rates to go into effect on November 1, 2012 on a temporary basis subject to revision. The rates resulted in a decrease to the rates charged to customers under the PGA. On May 1, 2013, the Washington Commission approved the proposed rates and allowed them to be made permanent. The estimated revenue impact of the approved change is a decrease of $77.0 million, or 7.7% annually, with no impact on net operating income.
On October 30, 2013, the Washington Commission approved PSE's PGA natural gas tariff, effective on November 1, 2013, which reflected changes in wholesale gas and pipeline transportation costs and changes in deferral amortization rates. The estimated revenue impact of the approved change is an increase of $4.0 million, or 0.4% annually, with no impact on net operating income.
The following table sets forth natural gas rate adjustments that were approved by the Washington Commission and the corresponding impact to PSE’s annual revenue based on the effective dates:
Type of Rate	Effective Date	Average	Annual
Adjustment		Percentage	Increase (Decrease)
		Increase (Decrease)	in Revenue
		in Rates	(Dollars in Millions)
Purchased Gas Adjustment	1-Nov-13	0.40%	$4.00
Decoupling Rate Filing	1-Jul-13	1.1	10.8
Expedited Rate Filing	1-Jul-13	-0.2	-2
Purchased Gas Adjustment	1-Nov-12	-7.7	-77
Natural Gas General Rate Case	14-May-12	1.3	13.4
Purchased Gas Adjustment	1-Nov-11	-4.3	-43.5
Natural Gas General Tariff Adjustment	1-Apr-11	1.8	19
In addition, PSE will be increasing the allowed delivery revenue per customer under the ERF filing by 2.2% for natural gas customers on January 1 of each year until the conclusion of PSE's next general rate case.
Environmental Remediation
The Company is subject to environmental laws and regulations by the federal, state and local authorities and is required to undertake certain environmental investigative and remedial efforts as a result of these laws and regulations.  The Company has been named by the Environmental Protection Agency (EPA), the Washington State Department of Ecology and/or other third parties as potentially responsible at several contaminated sites and manufactured gas plant sites.  PSE has implemented an ongoing program to test, replace and remediate certain underground storage tanks (UST) as required by federal and state laws.  The UST replacement component of this effort is finished, but PSE continues its work remediating and/or monitoring relevant sites.  During 1992, the Washington Commission issued orders regarding the treatment of costs incurred by the Company for certain sites under its environmental remediation program.  The orders authorize the Company to accumulate and defer prudently incurred cleanup costs paid to third parties for recovery in rates established in future rate proceedings, subject to Washington Commission review.  The Washington Commission consolidated the gas and electric methodological approaches to remediation and deferred accounting in an order issued October 8, 2008.  Per the guidance of ASC 450, “Contingencies,” the Company reviews its estimated future obligations and adjusts loss reserves quarterly.  Management believes it is probable and reasonably estimable that the impact of the potential outcomes of disputes with certain property owners and other potentially responsible parties will result in environmental remediation costs ranging from $31.3 million to $49.5 million for gas and from $9.1 million to $27.4 million for electric.  The Company does not consider any amounts within those ranges as being a better estimate and has therefore accrued $31.3 million and $9.1 million for gas and electric, respectively.  The Company believes a significant portion of its past and future environmental remediation costs are recoverable from insurance companies, from third parties or from customers under a Washington Commission order.  The Company is also subject to a cost-sharing agreement with a third party regarding an environmental remediation project in Seattle, Washington. The Company has taken the lead for completing the project. As of December 31, 2013, the Company’s share of remediation costs is estimated to be approximately $19.4 million. For the year ended December 31, 2013, the Company incurred deferred electric and natural gas environmental costs of $12.3 million and $45.1 million, net of insurance proceeds, respectively.

Dividend_Payment_Restrictions

Dividend Payment Restrictions	12 Months Ended
	Dec. 31, 2013
Dividend Payment Restrictions [Abstract]	'
Dividend Payment Restrictions	'
	Dividend Payment Restrictions
	The payment of dividends by PSE to Puget Energy is restricted by provisions of certain covenants applicable to long-term debt contained in PSE’s electric and natural gas mortgage indentures.  At December 31, 2013, approximately $469.6 million of unrestricted retained earnings was available for the payment of dividends under the most restrictive mortgage indenture covenant.
	Beginning February 6, 2009, pursuant to the terms of the Washington Commission merger order, PSE may not declare or pay dividends if PSE’s common equity ratio, calculated on a regulatory basis, is 44.0% or below except to the extent a lower equity ratio is ordered by the Washington Commission.  Also, pursuant to the merger order, PSE may not declare or make any distribution unless on the date of distribution PSE’s corporate credit/issuer rating is investment grade, or, if its credit ratings are below investment grade, PSE’s ratio of Adjusted Earnings Before Interest, Tax, Depreciation and Amortization (EBITDA) to interest expense for the most recently ended four fiscal quarter periods prior to such date is equal to or greater than 3 to one.  The common equity ratio, calculated on a regulatory basis, was 47.4% at December 31, 2013 and the EBITDA to interest expense was 4.4 to one for the 12 months then ended.
	PSE’s ability to pay dividends is also limited by the terms of its credit facilities, pursuant to which PSE is not permitted to pay dividends during any Event of Default (as defined in the facilities), or if the payment of dividends would result in an Event of Default, such as failure to comply with certain financial covenants.
	Puget Energy’s ability to pay dividends is also limited by the merger order issued by the Washington Commission as well as by the terms of its credit facilities.  Pursuant to the merger order, Puget Energy may not declare or make a distribution unless on such date Puget Energy’s ratio of consolidated EBITDA to consolidated interest expense for the four most recently ended fiscal quarters prior to such date is equal to or greater than 2 to one.  At December 31, 2013, the EBITDA to interest expense was 2.9 to one for the 12 months then ended.
	At December 31, 2013, the Company was in compliance with all applicable covenants, including those pertaining to the payment of dividends.

Utility_Plant

Utility Plant	12 Months Ended
	Dec. 31, 2013
Utility Plant [Abstract]	'
Utility Plant	'
	Utility Plant
			Puget Energy						Puget Sound Energy
	Utility Plant	Estimated	At December 31,						At December 31,
		Useful Life
	(Dollars In Thousands)	(Years)	2013			2012			2013			2012
	Electric, gas and common utility plant classified by prescribed accounts :
	Distribution plant	Oct-50	$	4,448,451		$	4,276,123		$	6,127,732		$	5,993,055
	Production plant	25-125	2,966,223			2,480,135			3,948,270			3,464,528
	Transmission plant	45-65	1,043,605			984,018			1,162,929			1,108,104
	General plant	May-35	504,965			445,982			599,156			543,195
	Intangible plant (including capitalized software)	Mar-50	316,614			181,884			309,972			181,596
	Plant acquisition adjustment	30-Jul	242,826			242,659			282,792			282,624
	Underground storage	25-60	27,857			27,331			41,501			40,987
	Liquefied natural gas storage	25-45	12,622			12,622			14,492			14,492
	Plant held for future use	NA	28,742			18,416			28,895			18,568
	Recoverable Cushion Gas	NA	8,655			8,655			8,655			8,655
	Plant not classified	NA	124,589			155,626			124,589			155,625
	Capital leases, net of accumulated amortization 1	5	17,051			24,629			17,051			24,629
	Less: accumulated provision for depreciation		(1,373,178		)	(1,067,424		)	(4,297,012		)	(4,045,402		)
	Subtotal		$	8,369,022		$	7,790,656		$	8,369,022		$	7,790,656
	Construction work in progress	NA	310,318			766,035			310,318			766,035
	Net utility plant		$	8,679,340		$	8,556,691		$	8,679,340		$	8,556,691
	_______________
	1	Accumulated amortization of capital leases at Puget Energy was $20.8 million in 2013 and $13.3 million in 2012.  Accumulated amortization of capital leases at PSE was $20.8 million in 2013 and $13.3 million in 2012.
	Jointly owned generating plant service costs are included in utility plant service cost at the Company's ownership share.  The following table indicates the Company’s percentage ownership and the extent of the Company’s investment in jointly owned generating plants in service at December 31, 2013.  These amounts are also included in the Utility Plant table above.
					Puget Energy’s						Puget Sound Energy’s
					Share						Share
	Jointly Owned Generating Plants	Energy Source (Fuel)	Company’s Ownership Share		Plant in Service at Cost			Accumulated Depreciation			Plant in Service at Cost			Accumulated Depreciation
	(Dollars in Thousands)
	Colstrip Units 1 & 2	Coal	50	%	$	162,090		$	(20,875	)	$	297,494		$	(156,278	)
	Colstrip Units 3 & 4	Coal	25	%	234,984			(33,270		)	513,992			(312,278		)
	Colstrip Units 1 – 4 Common Facilities	Coal	various		83			(17		)	252			(185		)
	Frederickson 1	Gas	49.85	%	61,785			(4,255		)	70,719			(13,189		)
	The Company recognized new Asset Retirement Obligations (ARO) of $0.4 million and $7.7 million in 2013 and 2012, respectively.
	The following table describes all changes to the Company’s ARO liability:
		At December 31,
	(Dollars in Thousands)	2013			2012
	Asset retirement obligation at beginning of period	$	45,496		$	26,540
	New asset retirement obligation recognized in the period	350			7,737
	Liability settled in the period	(1,188		)	(2,960		)
	Revisions in estimated cash flows	2,769			12,632
	Accretion expense	1,260			1,547
	Asset retirement obligation at end of period	$	48,687		$	45,496
	The Company has identified the following obligations, as defined by ASC 410, “Asset Retirement and Environmental Obligations,” which were not recognized because the liability for these assets cannot be reasonably estimated at December 31, 2013 due to:
	•	a legal obligation under Federal Dangerous Waste Regulations to dispose of asbestos-containing material in facilities that are not scheduled for remodeling, demolition or sales. The disposal cost related to these facilities could not be measured since the retirement date is indeterminable; therefore, the liability cannot be reasonably estimated;
	•	an obligation under Washington state law to decommission the wells at the Jackson Prairie natural gas storage facility upon termination of the project.  Since the project is expected to continue as long as the Northwest pipeline continues to operate, the liability cannot be reasonably estimated;
	•	an obligation to pay its share of decommissioning costs at the end of the functional life of the major transmission lines.  The major transmission lines are expected to be used indefinitely; therefore, the liability cannot be reasonably estimated.
	•	a legal obligation under Washington state environmental laws to remove and properly dispose of certain under and above ground fuel storage tanks.  The disposal costs related to under and above ground storage tanks could not be measured since the retirement date is indeterminable; therefore, the liability cannot be reasonably estimated;
	•	an obligation to pay decommissioning costs at the end of utility service franchise agreements to restore the surface of the franchise area. The decommissioning costs related to facilities at the franchise area could not be measured since the decommissioning date is indeterminable; therefore, the liability cannot be reasonably estimated; and
	•	a potential legal obligation may arise upon the expiration of an existing FERC hydropower license if FERC orders the project to be decommissioned, although PSE contends that FERC does not have such authority.  Given the value of ongoing generation, flood control and other benefits provided by these projects, PSE believes that the potential for decommissioning is remote and cannot be reasonably estimated.

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2013
Long-term Debt, Unclassified [Abstract]	'
Long-term Debt	'
	(6)  Long-Term Debt
	(Dollars in Thousands)			At December 31,
	Series	Type	Due	2013			2012
	Puget Sound Energy:
	6.83%	First Mortgage Bond	2013	$	—		$	3,000
	6.90%	First Mortgage Bond	2013	—			10,000
	7.35%	First Mortgage Bond	2015	10,000			10,000
	7.36%	First Mortgage Bond	2015	2,000			2,000
	5.20%	Senior Secured Note	2015	150,000			150,000
	6.75%	Senior Secured Note	2016	250,000			250,000
	5.50%	Promissory Note 1	2017	2,412			2,412
	6.74%	Senior Secured Note	2018	200,000			200,000
	7.15%	First Mortgage Bond	2025	15,000			15,000
	7.20%	First Mortgage Bond	2025	2,000			2,000
	7.02%	Senior Secured Note	2027	300,000			300,000
	7.00%	Senior Secured Note	2029	100,000			100,000
	3.90%	Pollution Control Bond	2031	138,460			—
	4.00%	Pollution Control Bond	2031	23,400			—
	5.00%	Pollution Control Bond	2031	—			138,460
	5.10%	Pollution Control Bond	2031	—			23,400
	5.48%	Senior Secured Note	2035	250,000			250,000
	6.72%	Senior Secured Note	2036	250,000			250,000
	6.27%	Senior Secured Note	2037	300,000			300,000
	5.76%	Senior Secured Note	2039	350,000			350,000
	5.80%	Senior Secured Note	2040	325,000			325,000
	5.76%	Senior Secured Note	2040	250,000			250,000
	4.43%	Senior Secured Note	2041	250,000			250,000
	5.64%	Senior Secured Note	2041	300,000			300,000
	4.70%	Senior Secured Note	2051	45,000			45,000
	6.97%	Junior Subordinated Note	2067	250,000			250,000
		Unamortized discount on senior notes		(14		)	(14		)
	PSE long-term debt			$	3,763,258		$	3,776,258
	Puget Energy:
		Fair value adjustment of PSE long-term debt		$	(229,746	)	$	(264,017	)
		Credit Facility	2017	299,000			434,000
	6.50%	Senior Secured Note	2020	450,000			450,000
	6.00%	Senior Secured Note	2021	500,000			500,000
	5.63%	Senior Secured Note	2022	450,000			450,000
		Unamortized discount on senior notes		(36		)	(41		)
	Total Puget Energy long-term debt			$	5,232,476		$	5,346,200
	_______________
	1	Puget Western, Inc., a wholly owned subsidiary of PSE, Promissory Note.
	PSE's senior secured notes will cease to be secured by the pledged first mortgage bonds on the date that all of the first mortgage bonds issued and outstanding under the electric or natural gas utility mortgage indenture have been retired.  As of December 31, 2013, the latest maturity date of the first mortgage bonds, other than pledged first mortgage bonds, is December 22, 2025.
	Puget Sound Energy Long-Term Debt
	PSE has in effect a shelf registration statement under which it may issue, from time to time, up to $800 million aggregate principal amount of senior notes secured by pledged first mortgage bonds.  The Company remains subject to the restrictions of PSE’s indentures and credit agreements on the amount of first mortgage bonds that PSE may issue.
	Substantially all utility properties owned by PSE are subject to the lien of the Company’s electric and natural gas mortgage indentures.  To issue additional first mortgage bonds under these indentures, PSE’s earnings available for interest must exceed certain minimums as defined in the indentures.  At December 31, 2013, the earnings available for interest exceeded the required amount.
	Puget Sound Energy Pollution Control Bonds
	PSE has two series of Pollution Control Bonds (the Bonds) outstanding.  Amounts outstanding were borrowed from the City of Forsyth, Montana who obtained the funds from the sale of Customized Pollution Control Refunding Bonds issued to finance pollution control facilities at Colstrip Units 3 & 4.
	On May 23, 2013, PSE refinanced $161.9 million of the Bonds to a lower weighted average interest rate from 5.01% to 3.91%. The Bonds will mature on March 1, 2031. On or after March 1, 2023, the Company may elect to call the bonds at a redemption price of 100% of the principal amount thereof, without premium, plus accrued interest, if any, to the redemption date. Due to the refinance of the Bonds, Puget Energy wrote off $18.0 million of fair value related to the Bonds that were redeemed to interest expense.
	Each series of the Bonds is collateralized by a pledge of PSE’s first mortgage bonds, the terms of which match those of the Bonds.  No payment is due with respect to the related series of first mortgage bonds so long as payment is made on the Bonds.
	Puget Energy Long-Term Debt
	On June 15, 2012, Puget Energy issued $450.0 million of senior secured notes. Proceeds from the note offering were used to pay down $425.0 million of the revolving $859.0 million senior secured credit facility balance resulting in an outstanding balance of $434.0 million as of December 31, 2012. In 2013, an additional paydown of the senior secured credit facility resulted in a remaining balance at of $299.0 million at December 31, 2013.
	At the time of the merger in February 2009, Puget Energy entered into a $1.225 billion five-year term-loan and a $1.0 billion five-year capital expenditure credit facility for funding capital expenditures. On February 10, 2012, Puget Energy entered into a $1.0 billion five-year revolving senior secured credit facility. Concurrent with the closing of the new PSE credit facilities in February 2013, the Company reduced the size of Puget Energy's credit facility to $800.0 million. The Puget Energy revolving senior secured credit facility also has an accordion feature that, upon the banks' approval, would increase the size of the facility to $1.3 billion. All other terms and conditions of that facility remain unchanged from when it was committed in 2012. As a revolving facility, amounts borrowed may be repaid without a reduction in the size of the facility. Initial borrowings under this facility were used to repay debt outstanding under the term loan and capital expenditure credit facility and those agreements were terminated.
	The Puget Energy revolving senior secured credit facility contains usual and customary affirmative and negative covenants.  The agreement also contains two financial covenants based on the following ratios:  Group Funds From Operations (FFO) Coverage Ratio and Maximum Leverage Ratio, as defined in the agreement governing the senior secured credit facility.
	Long-Term Debt Maturities
	The principal amounts of long-term debt maturities for the next five years and thereafter are as follows:
	(Dollars in Thousands)	2014			2015			2016		2017		2018		Thereafter		Total
	Maturities of:
	PSE long-term debt	$	—		$	162,000		$	250,000	$	2,412	$	200,000	$	3,148,860	$	3,763,272
	Puget Energy long-term debt	—			—			—		299,000		—		1,400,000		1,699,000
	Puget Energy long-term debt	$	—		$	162,000		$	250,000	$	301,412	$	200,000	$	4,548,860	$	5,462,272
	Financial Covenants
	Puget Energy's credit facility contains financial covenants related to group FFO coverage and maximum leverage. As of December 31, 2013, the Company is in compliance with its long-term debt financial covenants.

Liquidity_Facilities_and_Other

Liquidity Facilities and Other Financing Arrangements	12 Months Ended
	Dec. 31, 2013
Liquidity Facilities and Other Financing Arrangements [Abstract]	'
Liquidity Facilities and Other Financing Arrangements	'
	Liquidity Facilities and Other Financing Arrangements
	As of December 31, 2013 and 2012, PSE had $162.0 million and $181.0 million in short-term debt outstanding, respectively, exclusive of the demand promissory note with Puget Energy.  Outside of the consolidation of PSE’s short-term debt, Puget Energy had no short-term debt outstanding in either year as borrowings under its credit facilities are classified as long-term.  PSE’s weighted-average interest rate on short-term debt, including borrowing rate, commitment fees and the amortization of debt issuance costs, during 2013 and 2012 was 3.93% and 6.49%, respectively.  As of December 31, 2013, PSE and Puget Energy had several committed credit facilities that are described below.
	Puget Sound Energy Credit Facilities
	On February 4, 2013, PSE entered into two new credit facilities and terminated its previous three credit facilities. The new credit facilities provide, in aggregate, $1.0 billion of short-term liquidity needs. These facilities consist of a $650.0 million revolving liquidity facility (which includes a liquidity letter of credit facility and a swingline facility) to be used for general corporate purposes, including a backstop to the Company's commercial paper program and a $350.0 million revolving energy hedging facility (which includes an energy hedging letter of credit facility). The $650.0 million liquidity facility includes a swingline feature allowing same day availability on borrowings up to $75.0 million. The new credit facilities also have an accordion feature that, upon the banks' approval, would increase the total size of these facilities to $1.450 billion.
	The credit agreements for these two replacement credit facilities contain similar terms and conditions, are syndicated among numerous lenders and mature in February 2018.  The credit agreements contain usual and customary affirmative and negative covenants, that among other things, place limitations on PSE's ability to incur additional indebtedness and liens, issue equity, pay dividends, transact with affiliates and make asset dispositions and investments.  The credit agreements also contain a financial covenant of total debt to total capitalization of 65% or less. PSE certifies its compliance with such covenants to participating banks each quarter. As of December 31, 2013, PSE was in compliance with all applicable covenants.
	The credit agreements provide PSE with the ability to borrow at different interest rate options.  The credit agreements allow PSE to borrow at the bank's prime rate or to make floating rate advances at the London Interbank Offer Rate (LIBOR) plus a spread that is based upon PSE's credit rating.  PSE must pay a commitment fee on the unused portion of the credit facilities.  The spreads and the commitment fee depend on PSE's credit ratings.  As of the date of this report, the spread to the LIBOR is 1.25% and the commitment fee is 0.175%.
	As of December 31, 2013, no amount was drawn and outstanding under PSE’s $650.0 million liquidity facility. A letter of credit in the amount of $3.0 million in support of contracts was outstanding under the facility, and $162.0 million was outstanding under the commercial paper program. A letter of credit in the amount of $1.0 million was outstanding under the $350.0 million facility supporting energy hedging.
	Demand Promissory Note  On June 1, 2006, PSE entered into a revolving credit facility with Puget Energy, in the form of a credit agreement and a Demand Promissory Note (Note) pursuant to which PSE may borrow up to $30.0 million from Puget Energy subject to approval by Puget Energy.  Under the terms of the Note, PSE pays interest on the outstanding borrowings based on the lower of the weighted-average interest rates of PSE’s outstanding commercial paper interest rate or PSE’s senior unsecured revolving credit facility.  Absent such borrowings, interest is charged at one-month LIBOR plus 0.25%.  At December 31, 2013, the outstanding balance of the Note was $29.6 million.  The outstanding balance and the related interest under the Note are eliminated by Puget Energy upon consolidation of PSE’s financial statements.
	Puget Energy Credit Facility At December 31, 2013, Puget Energy maintained an $800.0 million five-year revolving senior secured credit facility.  The Puget Energy revolving senior secured credit facility also has an accordion feature that, upon the banks' approval, would increase the size of the facility to $1.3 billion.
	The five-year revolving senior secured credit facility contains usual and customary affirmative and negative covenants. The agreement also contains two financial covenants based on the following ratios: Group Funds From Operations (FFO) Coverage Ratio and Maximum Leverage Ratio, as defined in the agreement governing the senior secured credit facility. As of December 31, 2013, Puget Energy was in compliance with all applicable covenants.
	The revolving senior secured credit facility provides Puget Energy the ability to borrow at different interest rate options and includes variable fee levels.  Interest rates may be based on the prime rate or LIBOR, plus a spread based on Puget Energy’s credit ratings.  Puget Energy must pay a commitment fee on the unused portion of the facility.  At December 31, 2013, $299.0 million was drawn and outstanding under the facility, the spread over LIBOR was 1.75% and the commitment fee was 0.30%. Puget Energy entered into interest rate swap contracts to manage the interest rate risk associated with the credit facility.

Leases

Leases	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
Leases	'
	Leases
	PSE leases buildings and assets under operating leases.    Certain leases contain purchase options, renewal options and escalation provisions.  Operating lease expenses net of sublease receipts were:
	(Dollars in Thousands)
	At December 31,
	2013	$	29,392
	2012	29,661
	2011	24,789
	Payments received for the subleases of properties were immaterial for each of the years ended 2013, 2012 and 2011.
	Future minimum lease payments for non-cancelable leases net of sublease receipts are:
	(Dollars in Thousands)
	At December 31,	Operating		Capital
	2014	$	16,603	$	8,160
	2015	16,963		8,160
	2016	18,922		2,718
	2017	18,852		—
	2018	16,051		—
	Thereafter	68,847		—
	Total minimum lease payments	$	156,238	$	19,038

Accounting_for_Derivative_Inst

Accounting for Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Accounting for Derivative Instruments and Hedging Activities	'
	Accounting for Derivative Instruments and Hedging Activities
	PSE employs various energy portfolio optimization strategies, but is not in the business of assuming risk for the purpose of realizing speculative trading revenue. The nature of serving regulated electric customers with its portfolio of owned and contracted electric generation resources exposes PSE and its customers to some volumetric and commodity price risks within the sharing mechanism of the PCA. Therefore, wholesale market transactions and related hedging strategies are focused on reducing costs and risks where feasible, thus reducing volatility in costs in the portfolio. In order to manage its exposure to the variability in future cash flows for forecasted energy transactions, PSE utilizes a programmatic hedging strategy which extends out three years. PSE's energy risk portfolio management function monitors and manages these risks using analytical models and tools. In order to manage risks effectively, PSE enters into forward physical electric and natural gas purchase and sale agreements, fixed-for-floating swap contracts, and commodity call/put options. The forward physical electric agreements are both fixed and variable (at index), while the physical natural gas contracts are variable with investment grade counterparties that do not require collateral calls on the contracts. To fix the price of wholesale electricity and natural gas, PSE may enter into fixed-for-floating swap (financial) contracts with various counterparties. PSE also utilizes natural gas call and put options as an additional hedging instrument to increase the hedging portfolio's flexibility to react to commodity price fluctuations.
	The Company manages its interest rate risk through the issuance of mostly fixed-rate debt with varied maturities. The Company utilizes internal cash from operations, borrowings under its commercial paper program, and its credit facilities to meet short-term funding needs. The Company may enter into swap instruments or other financial hedge instruments to manage the interest rate risk associated with these debts. As of December 31, 2013, Puget Energy had two interest rate swap contracts outstanding which extend to January 2017. PSE did not have any outstanding interest rate swap instruments.
	The following table presents the volumes, fair values and locations of the Company's derivative instruments recorded on the balance sheets:
	Puget Energy and	Year Ended December 31,
	Puget Sound Energy
	(Dollars in Thousands)	Volumes (millions)				Assets 1						Liabilities 2
		2013		2012		2013			2012			2013			2012
	Interest rate swap derivatives 3	$450.00		$450.00		$	—		$	—		$	13,223		$	21,524
	Electric portfolio derivatives	*		*		18,479			9,557			37,312			131,193
	Natural gas derivatives (MMBtus) 4	423.5		516.9		8,121			12,126			35,676			108,078
	Total derivative contracts					$	26,600		$	21,683		$	86,211		$	260,795
	Current					$	18,867		$	6,869		$	48,049		$	177,519
	Long-term					7,733			14,814			38,162			83,276
	Total derivative contracts					$	26,600		$	21,683		$	86,211		$	260,795
	___________
	1	Balance sheet location: Current and Long-term Unrealized gain on derivative instruments.
	2	Balance sheet location: Current and Long-term Unrealized loss on derivative instruments.
	3	Interest rate swap contracts are only held at Puget Energy.
	4	PSE had a net derivative liability and an offsetting regulatory asset of $27.6 million at December 31, 2013 and $96.0 million at December 31, 2012 related to contracts used to economically hedge the cost of physical gas purchased to serve natural gas customers. All fair value adjustments on derivatives relating to the natural gas business have been deferred in accordance with ASC 980, due to the PGA mechanism.
	*	Electric portfolio derivatives consist of electric generation fuel of 145.6 million One Million British Thermal Units (MMBtus) and purchased electricity of 8.6 million MWhs at December 31, 2013 and 129.7 million MMBtus and 10.7 million MWhs at December 31, 2012.
	For further details regarding the fair value of derivative instruments, see Note 10.
	ASU 2013-01 requires disclosure of both gross and net information for recognized derivative assets and liabilities. It is the Company's policy to record all derivative transactions on a gross basis at the contract level, without offsetting assets or liabilities. The Company generally enters into transactions using the following master agreements: WSPP, Inc. (WSPP) agreements which standardize physical power contracts; International Swaps and Derivatives Association (ISDA) agreements which standardize financial gas and electric contracts; and North American Energy Standards Board (NAESB) agreements which standardize physical gas contracts. The Company believes that such agreements reduce credit risk exposure because such agreements provide for the netting and offsetting of monthly payments as well as right of set-off in the event of counterparty default. The set-off provision can be used as a final settlement of accounts which extinguishes the mutual debts owed between the parties in exchange for a new net amount.
	The following tables present the potential effect of netting arrangements, including rights of set-off associated with the Company's derivative assets and liabilities:
	Puget Energy and Puget Sound Energy
	At December 31, 2013
	(Dollars in Thousands)	Gross Amounts Recognized in the Statement of Financial Position 1			Gross Amounts Offset in the Statement of Financial Position			Net of Amounts Presented in the Statement of Financial Position			Gross Amounts Not Offset in the Statement of Financial Position
											Commodity Contracts			Cash Collateral Received/Posted			Net Amount
	Assets
	Energy Derivative Contracts	$	26,600		$	—		$	26,600		$	(19,491	)	$	—		$	7,109
	Liabilities
	Energy Derivative Contracts	$	72,988		$	—		$	72,988		$	(19,491	)	$	—		$	53,497
	Interest Rate Swaps 2	$	13,223		$	—		$	13,223		$	—		$	—		$	13,223
	Puget Energy and Puget Sound Energy
	At December 31, 2012
	(Dollars in Thousands)	Gross Amounts Recognized in the Statement of Financial Position 1			Gross Amounts Offset in the Statement of Financial Position			Net of Amounts Presented in the Statement of Financial Position			Gross Amounts Not Offset in the Statement of Financial Position
											Commodity Contracts			Cash Collateral Received/Posted			Net Amount
	Assets
	Energy Derivative Contracts	$	21,683		$	—		$	21,683		$	(14,126	)	$	—		$	7,557
	Liabilities
	Energy Derivative Contracts	$	239,271		$	—		$	239,271		$	(14,126	)	$	—		$	225,145
	Interest Rate Swaps 2	$	21,524		$	—		$	21,524		$	—		$	—		$	21,524
	___________
	1.	All Derivative Contract deals are executed under ISDA, NAESB and WSPP Master Netting Agreements with Right of Offset.
	2	Interest Rate Swap Contracts are only held at Puget Energy.
	Due to the merger in 2009, Puget Energy recorded all derivative contracts at fair value as either assets or liabilities. Certain contracts meeting the criteria defined in ASC 815 were subsequently designated as NPNS or cash flow hedges, thereby causing differences in the derivative unrealized gains/losses to be recorded through earnings between Puget Energy and PSE. These differences will occur through February 2015.
	The following tables present the effect and locations of the Company's derivatives not designated as hedging instruments, recorded on the statements of income:
	Puget Energy		Year Ended December 31,
	(Dollars in Thousands)	Location	2013			2012			2011
	Interest rate contracts:	Other deductions	$	2,420		$	(4,288	)	$	(28,601	)
		Interest expense	(5,904		)	(29,727		)	(46,045		)
	Commodity contracts:
	Electric derivatives	Unrealized gain (loss) on derivative instruments, net 1	102,744			131,407			(23,171		)
		Electric generation fuel	(27,008		)	(66,762		)	(98,208		)
		Purchased electricity	(38,299		)	(138,551		)	(66,845		)
	Total gain (loss) recognized in income on derivatives		$	33,953		$	(107,921	)	$	(262,870	)
	___________
	1	For 2012 and 2011, the amounts differ from the amounts stated in the statements of income as they do not include amortization related to contracts that were recorded at fair value at the time of the February 2009 merger and subsequently designated as NPNS of $2.2 million for the year ended December 31, 2012 and $11.7 million for the year ended December 31, 2011.
	Puget Sound Energy		Year Ended December 31,
	(Dollars in Thousands)	Location	2013			2012			2011
	Commodity contracts:
	Electric derivatives	Unrealized gain (loss) on derivative instruments, net	$	98,880		$	119,120		$	(54,146	)
		Electric generation fuel	(27,008		)	(66,762		)	(98,208		)
	Purchased electricity	(38,299		)	(138,551		)	(66,845		)
Total gain (loss) recognized in income on derivatives		$	33,573		$	(86,193	)	$	(219,199	)
The unrealized gain or loss on derivative contracts is reported in the statement of cash flows under the operating activities section. However, at the time of the merger in 2009, all derivative contracts at Puget Energy were assessed to identify contracts that have a “more than an insignificant” fair value. If the fair value was greater than 10% of the notional value, the contract was deemed as having a financing element. For those contracts, the cash inflows (outflows) are presented in the financing activities section of the statement of cash flows. For the years ended December 31, 2013, 2012 and 2011, cash outflows related to financing activities of $34.3 million, $92.7 million and $182.7 million, respectively, were reported on Puget Energy's statement of cash flows.
For derivative instruments previously designated as cash flow hedges (including both commodity and interest rate swap contracts), the effective portion of the gain or loss on the derivative was recorded as a component of OCI, and then is reclassified into earnings in the same period(s) during which the hedged transaction affects earnings. During 2013, Puget Energy reclassified $0.7 million in losses from accumulated OCI into earnings. This was the result of paying down $135.0 million on Puget Energy's revolving senior secured credit facility, thus causing the related forecasted transactions (i.e., future interest payments associated with the debt pay down) to become remote of occurring.
Puget Energy and PSE expect $0.7 million and $2.1 million of losses, respectively, in accumulated OCI will be reclassified into earnings within the next twelve months. The Company does not attempt cash flow hedging for any new transactions and records all mark-to-market adjustments through earnings.
The following tables present the Company's pre-tax gain (loss) on derivatives that were previously in a cash flow hedge relationship, and subsequently reclassified out of accumulated OCI into income:
Puget Energy		Year Ended December 31,
(Dollars in Thousands)	Location	2013			2012			2011
Interest rate contracts:	Interest expense	$	(4,505	)	$	(17,811	)	$	(39,143	)
Commodity contracts:
Electric derivatives	Electric generation fuel	—			100			(679		)
	Purchased electricity	(57		)	(671		)	(1,698		)
Total		$	(4,562	)	$	(18,382	)	$	(41,520	)
Puget Sound Energy		Year Ended December 31,
(Dollars in Thousands)	Location	2013			2012			2011
Interest rate contracts:	Interest expense	$	(488	)	$	(488	)	$	(488	)
Commodity contracts:
Electric derivatives	Electric generation fuel	—			97			(20,625		)
	Purchased electricity	(3,922		)	(12,955		)	(12,726		)
Total		$	(4,410	)	$	(13,346	)	$	(33,839	)
The Company is exposed to credit risk primarily through buying and selling electricity and natural gas to serve its customers. Credit risk is the potential loss resulting from a counterparty's non-performance under an agreement. The Company manages credit risk with policies and procedures for, among other things, counterparty credit analysis, exposure measurement, exposure monitoring and exposure mitigation.
The Company monitors counterparties that have significant swings in credit default swap rates, have credit rating changes by external rating agencies, have changes in ownership or are experiencing financial distress. Where deemed appropriate, the Company may request collateral or other security from its counterparties to mitigate potential credit default losses. Criteria employed in this decision include, among other things, the perceived creditworthiness of the counterparty and the expected credit exposure.
It is possible that volatility in energy commodity prices could cause the Company to have material credit risk exposure with one or more counterparties. If such counterparties fail to perform their obligations under one or more agreements, the Company could suffer a material financial loss. However, as of December 31, 2013, approximately 99.9% of the Company's energy portfolio exposure, excluding NPNS transactions, is with counterparties that are rated at least investment grade by the major rating agencies and 0.1% are either rated below investment grade or not rated by rating agencies. The Company assesses credit risk internally for counterparties that are not rated.
As the Company generally enters into transactions using the WSPP, ISDA and NAESB master agreements, it believes that such agreements reduce credit risk exposure because they provide for the netting and offsetting of monthly payments and, in the event of counterparty default, termination payments.
The Company computes credit reserves at a master agreement level by counterparty (i.e., WSPP, ISDA, or NAESB). The Company considers external credit ratings and market factors, such as credit default swaps and bond spreads, in the determination of reserves. The Company recognizes that external ratings may not always reflect how a market participant perceives a counterparty's risk of default. The Company uses both default factors published by Standard & Poor's and factors derived through analysis of market risk, which reflect the application of an industry standard recovery rate. The Company selects a default factor by counterparty at an aggregate master agreement level based on a weighted-average default tenor for that counterparty's deals. The default tenor is used by weighting the fair value and contract tenors for all deals for each counterparty to derive an average value. The default factor used is dependent upon whether the counterparty is in a net asset or a net liability position after applying the master agreement levels.
The Company applies the counterparty's default factor to compute credit reserves for counterparties that are in a net asset position. The Company calculates a non-performance risk on its derivative liabilities by using its estimated incremental borrowing rate over the risk-free rate. Credit reserves are recorded as contra accounts to unrealized gain (loss) positions. As of December 31, 2013, the Company was in a net liability position with the majority of counterparties, so the default factors of counterparties did not have a significant impact on reserves for the quarter. The majority of the Company's derivative contracts are with financial institutions and other utilities operating within the Western Electricity Coordinating Council. As of December 31, 2013, PSE has posted a $1.0 million letter of credit as a condition of transacting on a physical energy exchange and clearinghouse in Canada. PSE did not trigger any collateral requirements with any of its counterparties nor were any of PSE's counterparties required to post collateral resulting from credit rating downgrades.
The table below presents the fair value of the overall contractual contingent liability positions for the Company's derivative activity at December 31, 2013:
Puget Energy and Puget Sound Energy	Fair Value 1			Posted			Contingent
Contingent Feature	Liability			Collateral			Collateral
(Dollars in Thousands)
Credit rating 2	$	(12,561	)	$	—		$	12,561
Requested credit for adequate assurance	(22,415		)	—			—
Forward value of contract 3	(49		)	—			—
Total	$	(35,025	)	$	—		$	12,561
__________
1	Represents the derivative fair value of contracts with contingent features for counterparties in net derivative liability positions. Excludes NPNS, accounts payable and accounts receivable.
2	Failure by PSE to maintain an investment grade credit rating from each of the major credit rating agencies provides counterparties a contractual right to demand collateral.
3	Collateral requirements may vary, based on changes in the forward value of underlying transactions relative to contractually defined collateral thresholds.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	Fair Value Measurements
	ASC 820 established a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy categorizes the inputs into three levels with the highest priority given to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority given to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows:
	Level 1 - Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Level 1 primarily consists of financial instruments such as exchange-traded derivatives and listed equities. Equity securities that are also classified as cash equivalents are considered Level 1 if there are unadjusted quoted prices in active markets for identical assets or liabilities.
	Level 2 - Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. Instruments in this category include non-exchange-traded derivatives such as over-the-counter forwards and options.
	Level 3 - Pricing inputs include significant inputs that have little or no observability as of the reporting date. These inputs may be used with internally developed methodologies that result in management's best estimate of fair value.
	Financial assets and liabilities measured at fair value are classified in their entirety in the appropriate fair value hierarchy based on the lowest level of input that is significant to the fair value measurement. The Company's assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy. The Company primarily determines fair value measurements classified as Level 2 or Level 3 using a combination of the income and market valuation approaches. The process of determining the fair values is the responsibility of the derivative accounting department which reports to the Controller and Principal Accounting Officer. Inputs used to estimate the fair value of forwards, swaps and options include market-price curves; contract terms and prices; credit-risk adjustments; and discount factors. Additionally, for options, the Black-Scholes option valuation model and implied market volatility curves are used. Inputs used to estimate fair value in industry-standard models are categorized as Level 2 inputs because substantially all assumptions and inputs are observable in active markets throughout the full term of the instruments. On a daily basis, the Company obtains quoted forward prices for the electric and natural gas markets from an independent external pricing service. For interest rate swaps, the Company obtains monthly mark-to-market values from an independent external pricing service for LIBOR forward rates, which is a significant input. Some of the inputs of the interest rate swap valuations, which are less significant, include the credit standing of the counterparties, assumptions for time value and the impact of the Company's nonperformance risk of its liabilities. The Company classifies cash and cash equivalents, and restricted cash as Level 1 financial instruments due to cash being at stated value, and cash equivalents at quoted market prices.
	The Company considers its electric, natural gas and interest rate swap contracts as Level 2 derivative instruments as such contracts are commonly traded as over-the-counter forwards with indirectly observable price quotes. Management's assessment was based on the trading activity in real-time and forward electric and natural gas markets. Each quarter, the Company confirms the validity of pricing-service quoted prices (e.g., Level 2 in the fair value hierarchy) used to value commodity contracts with the actual prices of commodity contracts entered into during the most recent quarter. However, certain energy derivative instruments with maturity dates falling outside the range of observable price quotes are classified as Level 3 in the fair value hierarchy.
	Assets and Liabilities with Estimated Fair Value
	The following table presents the carrying value for cash, cash equivalents, restricted cash, notes receivable and short-term debt by level, within the fair value hierarchy. The carrying values below are representative of fair values due to the short-term nature of these financial instruments.
	Puget Energy	Carrying / Fair Value									Carrying / Fair Value
		At December 31, 2013									At December 31, 2012
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	44,302		$	—		$	44,302		$	135,542		$	—		$	135,542
	Restricted Cash	7,171			—			7,171			3,700			—			3,700
	Notes Receivable and Other	—			53,449			53,449			—			63,802			63,802
	Total assets	$	51,473		$	53,449		$	104,922		$	139,242		$	63,802		$	203,044
	Liabilities:
	Short-term debt	$	162,000		$	—		$	162,000		$	181,000		$	—		$	181,000
	Total liabilities	$	162,000		$	—		$	162,000		$	181,000		$	—		$	181,000
	Puget Sound Energy	Carrying / Fair Value									Carrying / Fair Value
		At December 31, 2013									At December 31, 2012
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	44,111		$	—		$	44,111		$	135,530		$	—		$	135,530
	Restricted Cash	7,171			—			7,171			3,700			—			3,700
	Notes Receivable and Other	—			53,449			53,449			—			63,802			63,802
	Total assets	$	51,282		$	53,449		$	104,731		$	139,230		$	63,802		$	203,032
	Liabilities:
	Short-term debt	$	162,000		$	—		$	162,000		$	181,000		$	—		$	181,000
	Short-term debt owed to parent	—			29,598			29,598			—			29,598			29,598
	Total liabilities	$	162,000		$	29,598		$	191,598		$	181,000		$	29,598		$	210,598
	The fair value of the junior subordinated and long-term notes were estimated using the discounted cash flow method with U.S. Treasury yields and Company credit spreads as inputs, interpolating to the maturity date of each issue. Carrying values and estimated fair values were as follows:
	Puget Energy		December 31, 2013						December 31, 2012
	(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value
	Liabilities:
	Junior subordinated notes	2	$	250,000		$	269,366		$	250,000		$	264,842
	Long-term debt (fixed-rate), net of discount	2	4,683,476			5,594,314			4,662,200			6,197,179
	Long-term debt (variable-rate)	2	299,000			299,000			434,000			434,000
	Total		$	5,232,476		$	6,162,680		$	5,346,200		$	6,896,021
	Puget Sound Energy		December 31, 2013						December 31, 2012
	(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value
	Liabilities:
	Junior subordinated notes	2	$	250,000		$	269,366		$	250,000		$	264,842
	Long-term debt (fixed-rate), net of discount	2	3,513,258			4,038,455			3,526,258			4,628,509
	Total		$	3,763,258		$	4,307,821		$	3,776,258		$	4,893,351
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	The following tables present the Company's financial assets and liabilities by level, within the fair value hierarchy, that were accounted for at fair value on a recurring basis and the reconciliation of the changes in the fair value of Level 3 derivatives in the fair value hierarchy:
	Puget Energy	Fair Value									Fair Value
		At December 31, 2013									At December 31, 2012
	(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
	Interest rate derivative instruments	$	13,223		$	—		$	13,223		$	21,524		$	—		$	21,524
	Total derivative liabilities	$	13,223		$	—		$	13,223		$	21,524		$	—		$	21,524
	Puget Energy and	Fair Value									Fair Value
	Puget Sound Energy	At December 31, 2013									At December 31, 2012
	(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
	Assets:
	Electric derivative instruments	$	14,661		$	3,818		$	18,479		$	1,259		$	8,298		$	9,557
	Natural gas derivative instruments	5,448			2,673			8,121			6,769			5,357			12,126
	Total assets	$	20,109		$	6,491		$	26,600		$	8,028		$	13,655		$	21,683
	Liabilities:
Electric derivative instruments	$	18,073		$	19,239		$	37,312		$	88,971		$	42,221		$	131,192
Natural gas derivative instruments	32,642			3,034			35,676			101,119			6,960			108,079
Total liabilities	$	50,715		$	22,273		$	72,988		$	190,090		$	49,181		$	239,271
Puget Energy and	Year Ended December 31,
Puget Sound Energy
Level 3 Roll-Forward Net (Liability)	2013									2012									2011
(Dollars in Thousands)	Electric			Gas			Total			Electric			Gas			Total			Electric			Gas			Total
Balance at beginning of period	$	(33,924	)	$	(1,602	)	$	(35,526	)	$	(90,311	)	$	(5,041	)	$	(95,352	)	$	(87,436	)	$	(3,859	)	$	(91,295	)
Changes during period
Realized and unrealized energy derivatives:
Included in earnings 1	(10,491		)	—			(10,491		)	(21,362		)	—			(21,362		)	(56,499		)	—			(56,499		)
Included in regulatory assets / liabilities	—			(945		)	(945		)	—			(1,937		)	(1,937		)	—			(250		)	(250		)
Settlements 2	11,609			(754		)	10,855			59,133			969			60,102			40,900			(3,418		)	37,482
Transferred into Level 3	(7,799		)	—			(7,799		)	(55,548		)	(297		)	(55,845		)	(759		)	453			(306		)
Transferred out of Level 3	25,184			2,940			28,124			74,164			4,704			78,868			13,483			2,033			15,516
Balance at end of period	$	(15,421	)	$	(361	)	$	(15,782	)	$	(33,924	)	$	(1,602	)	$	(35,526	)	$	(90,311	)	$	(5,041	)	$	(95,352	)
_______________
1	Income Statement location: Unrealized (gain) loss on derivative instruments, net. Includes unrealized gains (losses) on derivatives still held in position as of the reporting date for electric derivatives of $(13.4) million, $(15.2) million, and $(55.2) million for the years ended December 31, 2013, 2012 and 2011, respectively.
2	The Company had no purchases, sales or issuances during the reported periods.
Realized gains and losses on energy derivatives for Level 3 recurring items are included in energy costs in the Company's consolidated statements of income under purchased electricity, electric generation fuel or purchased natural gas when settled. Unrealized gains and losses on energy derivatives for Level 3 recurring items are included in net unrealized (gain) loss on derivative instruments in the Company's consolidated statements of income.
In order to determine which assets and liabilities are classified as Level 3, the Company receives market data from its independent external pricing service defining the tenor of observable market quotes. To the extent any of the Company's commodity contracts extend beyond what is considered observable as defined by its independent pricing service, the contracts are classified as Level 3. The actual tenor of what the independent pricing service defines as observable is subject to change depending on market conditions. Therefore, as the market changes, the same contract may be designated Level 3 one month and Level 2 the next, and vice versa. The changes of fair value classification into or out of Level 3 are recognized each month, and reported in the Level 3 Roll-forward table above. The Company did not have any transfers between Level 2 and Level 1 during the years ended December 31, 2013 and 2012. The Company does periodically transact at locations, or market price points, that are illiquid or for which no prices are available from the independent pricing service. In such circumstances the Company uses a more liquid price point and performs a 15-month regression against the illiquid locations to serve as a proxy for market prices. Such transactions are classified as Level 3. The Company does not use internally developed models to make adjustments to significant unobservable pricing inputs.
The only significant unobservable input into the fair value measurement of the Company's Level 3 assets and liabilities is the forward price for electric and natural gas contracts. Below are the forward price ranges for the Company's purchased commodity contracts, as of December 31, 2013:
(Dollars in Thousands)
	Fair Value				Range
Derivative Instrument	Assets 1	Liabilities 1	Valuation Technique	Unobservable Input	Low	High	Weighted Average
Electric	$3,818	$19,239	Discounted cash flow	Power Prices	$17.06 per MWh	$47.09 per MWh	$38.74 per MWh
Natural gas	$2,673	$3,034	Discounted cash flow	Natural Gas Prices	$3.62 per MMBtu	$4.19 per MMBtu	$3.78 per MMBtu
_______________
1	The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions.
The significant unobservable inputs listed above would have a direct impact on the fair values of the above instruments if they were adjusted. Consequently significant increases or decreases in the forward prices of electricity or natural gas in isolation would result in a significantly higher or lower fair value for Level 3 assets and liabilities. Generally, interrelationships exist between market prices of natural gas and power. As such, an increase in natural gas pricing would potentially have a similar impact on forward power markets. At December 31, 2013, a hypothetical 10% increase or decrease in market prices of natural gas and electricity would change the fair value of the Company's derivative portfolio, classified as Level 3 within the fair value hierarchy, by $7.0 million.
Long-Lived Assets Measured at Fair Value on a Nonrecurring Basis
At the time of merger, Puget Energy recorded the fair value of its intangible assets in accordance with ASC 360, “Property, Plant, and Equipment,” (ASC 360). The fair value assigned to the power contracts was determined using an income approach comparing the contract rate to the market rate for power over the remaining period of the contracts incorporating non-performance risk. Management also incorporated certain assumptions related to quantities and market presentation that it believes market participants would make in the valuation. The fair value of the power contracts is amortized as the contracts settle.
ASC 360 requires long-lived assets to be tested for impairment on an annual basis, and upon the occurrence of any events or circumstances that would be more likely than not to reduce the fair value of the long-lived assets below their carrying value. One such triggering event is a significant decrease in the forward market prices of power.
At June 30, 2013, Puget Energy completed a valuation and impairment test of its purchased power contracts classified as intangible assets. The valuation indicated a fair value of $484.1 million with an impairment to the Priest Rapids Reasonable Portion intangible asset contract. As of June 30, 2013, the carrying value for this intangible asset contract was $47.1 million and its fair value on a discounted basis was determined to be an asset of $33.6 million, thereby requiring a write-down of $13.5 million to the intangible asset with a corresponding reduction in the regulatory liability.
The valuation was measured using the income approach. Significant inputs included forward electricity prices and power contract pricing which provided future net cash flow estimates which are classified as Level 3 within the fair value hierarchy. A less significant input is the discount rate reflective of PSE's cost of capital used in the valuation.
Below are significant unobservable inputs used in estimating the long-term power purchase contracts' fair value of $484.1 million on June 30, 2013:
Valuation Technique	Unobservable Input	Low	High	Weighted Average
Discounted cash flow	Power prices	$30.85 per MWh	$65.35 per MWh	$48.47 per MWh
Discounted cash flow	Power contract costs (in thousands)	$389 per yr	$6,845 per yr	$4,110 per yr
During 2012, Puget Energy completed valuation and impairment testing of its purchased power contracts classified as intangible assets.  At March 31, 2012, the Wells Hydro intangible asset contract had a carrying value of $113.3 million and a fair value on a discounted basis of $96.7 million, thereby requiring a write-down of $16.6 million of this intangible asset and a corresponding reduction in the regulatory liability. Additionally, at December 31, 2012, the Rock Island intangible asset contract had a carrying value of $7.6 million and its fair value on a discounted basis was determined to be a liability of $10.2 million, thereby requiring a complete write-off of this intangible asset and a corresponding reduction in the regulatory liability.
Below are significant unobservable inputs used in estimating the long-term power purchase contracts' fair value on March 31, 2012 and December 31, 2012:
Valuation Technique	Unobservable Input	Low	High	Weighted Average
March 31, 2012
Discounted cash flow	Power prices	$10.36 per MWh	$49.78 per MWh	$34.98 per MWh
Discounted cash flow	Power contract costs (in thousands)	$3,185 per qtr	$5,030 per qtr	$4,663 per qtr
December 31, 2012
Discounted cash flow	Power prices	$16.94 per MWh	$70.89 per MWh	$49.40 per MWh
Discounted cash flow	Power contract costs (in thousands)	$1,777 per qtr	$7,133 per qtr	$6,603 per qtr

Employee_Investment_Plans

Employee Investment Plans	12 Months Ended
	Dec. 31, 2013
Employee Investment Plans [Abstract]	'
Employee Investment Plans	'
	Employee Investment Plans
	The Company's existing plan is a qualified employee Investment Plan 401(k) plan, under which employee salary deferrals and after-tax contributions are used to purchase several different investment fund options.  For employees under the Cash Balance retirement plan formula, PSE will match 100% of an employee's contribution up to 6% of plan compensation, and will make an additional year-end contribution equal to 1% of base pay.  For employees grandfathered under the Final Average Earning retirement plan formula, PSE will match 55% of an employee’s contribution up to 6% of plan compensation. PSE’s contributions to the employee Investment Plan were $14.6 million, $14.5 million and $13.5 million for the years 2013, 2012, and 2011, respectively.  The employee Investment Plan eligibility requirements are set forth in the plan documents.
	Beginning January 1, 2014 employees hired as of this date will have access to the 401(k) plan and will choose how they want to accumulate funds for retirement, with two contribution sources from PSE:
	•	401(k) Company Matching: new non-represented and United Association of Plumbers and Pipefitters (UA) employees will receive company match each paycheck based on a new schedule-100% match on the first 3% of pay contributed and 50% match on the next 3% of pay contributed. An employee who contributes 6% of pay will receive 4.5% of pay in company match. Company matching will be immediately vested.
	•	Company Contribution: 401(k) or pension plan. New non-represented employees will receive an annual company contribution of 4% of eligible pay, placed either in the Investment Plan 401(k) plan or an account in PSE’s Retirement Plan (Cash Balance pension plan). New employees will make a one-time election within 30 days of hire and direct that PSE put the 4% contribution either into the 401(k) plan or into an account in the Cash Balance pension plan. The Company’s 4% contribution will vest after three years of employment.

Retirement_Benefits

Retirement Benefits	12 Months Ended
	Dec. 31, 2013
Compensation and Retirement Disclosure [Abstract]	'
Retirement Benefits	'
	Retirement Benefits
	PSE has a defined benefit pension plan covering substantially all PSE employees.  Pension benefits earned are a function of age, salary, years of service and, in the case of employees in the cash balance formula plan, the applicable annual interest crediting rates.  Beginning January 1, 2014, all new UA employees and those new non-represented employees who elect to accumulate the Company contribution in the Cash Balance pension, will receive annual pay credits of 4% each year. They will also receive interest credits like other participants in the Cash Balance pension, which are at least 1% per quarter. When a newly-hired employee with a vested Cash Balance benefit leaves PSE, he or she will have annuity and lump sum options for distribution, with annuities calculated according to the Pension Protection Act. Those who select the lump sum option will receive their current cash balance amount.
	In addition to providing pension benefits, PSE provides group health care and life insurance benefits for certain retired employees.  PSE also maintains a non-qualified Supplemental Executive Retirement Plan (SERP) for its key senior management employees. These benefits are provided principally through an insurance company.  The insurance premiums, paid primarily by retirees, are based on the benefits provided during the year.
	The 2009 merger of Puget Energy with Puget Holdings triggered a new basis of accounting for PSE’s retirement benefit plans in the Puget Energy consolidated financial statements.  Such purchase accounting adjustments associated with the remeasurement of the retirement plans are recorded at Puget Energy.
	The following tables summarize the Company’s change in benefit obligation, change in plan assets and amounts recognized in the Statements of Financial Position for the years ended December 31, 2013 and 2012:
	Puget Energy and	Qualified						SERP						Other
	Puget Sound Energy	Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Change in benefit obligation:
	Benefit obligation at beginning of period	$	616,290		$	565,997		$	51,795		$	48,370		$	17,672		$	16,436
	Service cost	19,285			16,926			1,498			1,073			134			139
	Interest cost	24,754			25,986			2,045			2,152			664			751
	Amendment	—			—			478			(122		)	—			—
	Actuarial loss/(gain)	(48,559		)	40,914			(1,687		)	5,483			(2,240		)	1,199
	Benefits paid	(38,453		)	(33,533		)	(6,850		)	(5,161		)	(1,536		)	(1,523		)
	Medicare part D subsidy received	—			—			—			—			245			670
	Benefit obligation at end of period	$	573,317		$	616,290		$	47,279		$	51,795		$	14,939		$	17,672
	Puget Energy and	Qualified						SERP						Other
	Puget Sound Energy	Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Change in plan assets:
	Fair value of plan assets at beginning of period	$	531,183		$	479,786		$	—		$	—		$	7,541		$	7,206
	Actual return on plan assets	102,591			62,130			—			—			1,861			1,100
	Employer contribution	20,400			22,800			6,850			5,161			908			758
	Benefits paid	(38,453		)	(33,533		)	(6,850		)	(5,161		)	(1,536		)	(1,523		)
	Fair value of plan assets at end of period	$	615,721		$	531,183		$	—		$	—		$	8,774		$	7,541
	Funded status at end of period	$	42,404		$	(85,107	)	$	(47,279	)	$	(51,795	)	$	(6,165	)	$	(10,131	)
	Puget Energy and	Qualified						SERP						Other
	Puget Sound Energy	Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Amounts recognized in Statement of Financial Position consist of:
	Noncurrent assets	$	42,404		$	—		$	—		$	—		$	—		$	—
	Current liabilities	—			—			(3,981		)	(5,040		)	(421		)	(460		)
	Noncurrent liabilities	—			(85,107		)	(43,298		)	(46,755		)	(5,744		)	(9,671		)
	Net assets / (liabilities)	$	42,404		$	(85,107	)	$	(47,279	)	$	(51,795	)	$	(6,165	)	$	(10,131	)
	The following tables summarize Puget Energy and Puget Sound Energy's pension benefit amounts recognized in Accumulated Other Comprehensive income for the years ended December 31, 2013 and 2012:
	Puget Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Amounts recognized in Accumulated Other Comprehensive Income consist of:
	Net loss/(gain)	$	(65,943	)	$	49,001		$	9,670		$	12,818		$	(2,972	)	$	763
	Prior service cost / (credit)	(15,762		)	(17,741		)	373			(122		)	—			—
	Total	$	(81,705	)	$	31,260		$	10,043		$	12,696		$	(2,972	)	$	763
	Puget Sound Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Amounts recognized in Accumulated Other Comprehensive Income consist of:
	Net loss/(gain)	$	138,324		$	269,401		$	14,050		$	17,928		$	(5,556	)	$	(2,175	)
	Prior service cost/(credit)	(12,525		)	(14,098		)	383			(110		)	6			36
	Total	$	125,799		$	255,303		$	14,433		$	17,818		$	(5,550	)	$	(2,139	)
	The following tables summarize Puget Energy's and Puget Sound Energy's net periodic benefit cost for the years ended December 31, 2013, 2012 and 2011:
	Puget Energy	Qualified									SERP									Other
		Pension Benefits									Pension Benefits									Benefits
	(Dollars in Thousands)	2013			2012			2011			2013			2012			2011			2013			2012			2011
	Components of net periodic benefit cost:
	Service cost	$	19,285		$	16,926		$	15,822		$	1,498		$	1,073		$	1,241		$	134		$	139		$	113
	Interest cost	24,754			25,986			26,263			2,045			2,152			2,192			664			751			806
	Expected return on plan assets	(39,095		)	(36,203		)	(35,344		)	—			—			—			(436		)	(435		)	(502		)
	Amortization of prior service cost/(credit)	(1,980		)	(1,980		)	(1,980		)	(17		)	—			—			—			—			—
	Amortization of net loss	2,889			768			—			1,461			702			360			69			53			(46		)
	Net periodic benefit cost	$	5,853		$	5,497		$	4,761		$	4,987		$	3,927		$	3,793		$	431		$	508		$	371
	Puget Sound Energy	Qualified									SERP									Other
		Pension Benefits									Pension Benefits									Benefits
(Dollars in Thousands)	2013			2012			2011			2013			2012			2011			2013			2012			2011
Components of net periodic benefit cost:
Service cost	$	19,285		$	16,926		$	15,822		$	1,498		$	1,073		$	1,241		$	134		$	139		$	113
Interest cost	24,753			25,986			26,263			2,045			2,152			2,192			664			751			806
Expected return on plan assets	(40,685		)	(41,533		)	(44,128		)	—			—			—			(436		)	(435		)	(502		)
Amortization of prior service cost/(credit)	(1,573		)	(1,573		)	(1,573		)	(16		)	293			563			30			35			63
Amortization of net loss/(gain)	20,612			15,015			10,250			2,191			1,432			1,194			(284		)	(245		)	(481		)
Amortization of transition obligation	—			—			—			—			—			—			—			50			50
Net periodic benefit cost	$	22,392		$	14,821		$	6,634		$	5,718		$	4,950		$	5,190		$	108		$	295		$	49
The following tables summarize Puget Energy's and Puget Sound Energy's benefit obligations recognized in other comprehensive income for the years ended December 31, 2013 and 2012:
Puget Energy	Qualified						SERP						Other
	Pension Benefits						Pension Benefits						Benefits
(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
Other changes (pre-tax) in plan assets and benefit obligations recognized in other comprehensive income:
Net loss/(gain)	$	(112,055	)	$	14,988		$	(1,687	)	$	5,483		$	(3,665	)	$	534
Amortization of net loss/(gain)	(2,889		)	(768		)	(1,461		)	(703		)	(70		)	(53		)
Prior service credit	—			—			478			(122		)	—			—
Amortization of prior service credit	1,980			1,980			17			—			—			—
Total change in other comprehensive income for year	$	(112,964	)	$	16,200		$	(2,653	)	$	4,658		$	(3,735	)	$	481
Puget Sound Energy	Qualified						SERP						Other
	Pension Benefit						Pension Benefits						Benefits
(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
Other changes (pre-tax) in plan assets and benefit obligations recognized in other comprehensive income:
Net loss/(gain)	$	(110,465	)	$	20,318		$	(1,687	)	$	5,483		$	(3,665	)	$	534
Amortization of net (loss)/gain	(20,612		)	(15,015		)	(2,191		)	(1,433		)	284			245
Prior service cost/(credit)	—			—			477			(122		)	—			—
Amortization of prior service cost/(credit)	1,573			1,573			16			(293		)	(30		)	(35		)
Amortization of transition obligation	—			—			—			—			—			(50		)
Total change in other comprehensive income for year	$	(129,504	)	$	6,876		$	(3,385	)	$	3,635		$	(3,411	)	$	694
The estimated prior service cost/(credit) for the pension plans that will be amortized from accumulated OCI into net periodic benefit cost in 2014 by Puget Energy is $2.0 million.  The estimated net (loss)/gain for the SERP that will be amortized from accumulated OCI into net periodic benefit cost in 2014 is $(0.9) million. The estimated prior service cost/(credit) for the SERP that will be amortized from accumulated OCI into net periodic benefit cost in 2014 is immaterial.  The estimated net (loss)/gain, prior service cost/(credit) and transition/(obligation) asset for the other postretirement plans that will be amortized from accumulated OCI into net periodic benefit cost in 2014 are immaterial.
The estimated net (loss)/gain and prior service cost/(credit) for the pension plans that will be amortized from accumulated OCI into net periodic benefit cost in 2014 by Puget Sound Energy are $(13.0) million and $1.6 million, respectively.  The estimated net loss/(gain) and prior service cost/(credit) for the SERP that will be amortized from accumulated OCI into net periodic benefit cost in 2014 are $(1.5) million. The estimated prior service cost/(credit) for the SERP that will be amortized from accumulated OCI into net periodic benefit cost in 2014 is immaterial.  The estimated net (loss)/gain for the other postretirement plan that will be amortized from accumulated OCI into net periodic benefit cost in 2014 is $0.6 million and prior service cost/(credit) and transition (obligation)/asset for the other postretirement plans are immaterial.
The aggregate expected contributions by the Company to fund the retirement plan, SERP and the other postretirement plans for the year ending December 31, 2014 are expected to be at least $12.0 million, $4.0 million and $0.4 million, respectively.
Assumptions
In accounting for pension and other benefit obligations and costs under the plans, the following weighted-average actuarial assumptions were used by the Company:
	Qualified						SERP						Other
	Pension Benefits						Pension Benefits						Benefits
Benefit Obligation Assumptions	2013		2012		2011		2013		2012		2011		2013		2012		2011
Discount rate 1	5.1	%	4.15	%	4.75	%	5.1	%	4.15	%	4.75	%	5.1	%	4.15	%	4.75	%
Rate of compensation increase	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%
Medical trend rate	—		—		—		—		—		—		6.8	%	7.5	%	7.5	%
Benefit Cost Assumptions
Discount rate	4.15	%	4.75	%	5.15	%	4.15	%	4.75	%	5.15	%	4.15	%	4.75	%	5.15	%
Rate of plan assets	7.75	%	7.75	%	7.75	%	—		—		—		6.9	%	7.5	%	7.8	%
Rate of compensation increase	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%
Medical trend rate	—		—		—		—		—		—		8.2	%	7.5	%	8	%
_______________
1	The Company calculates the present value of the pension liability using a discount rate of 5.10% which represents the single-rate equivalent of the AA rated corporate bond yield curve.
The assumed medical inflation rate used to determine benefit obligations is 8.20% in 2014 grading down to 4.30% in 2015.  A 1.0% change in the assumed medical inflation rate would have the following effects:
	2013						2012
(Dollars in Thousands)	1% Increase			1% Decrease			1% Increase			1% Decrease
Effect on post-retirement benefit obligation	$	66		$	(66	)	$	92		$	(92	)
Effect on service and interest cost components	3			(3		)	4			(4		)
The Company has selected the expected return on plan assets based on a historical analysis of rates of return and the Company’s investment mix, market conditions, inflation and other factors.  The expected rate of return is reviewed annually based on these factors.  The Company’s accounting policy for calculating the market-related value of assets for the Company’s retirement plan is as follows.  PSE market-related value of assets is based on a five-year smoothing of asset gains/losses measured from the expected return on market-related assets.  This is a calculated value that recognizes changes in fair value in a systematic and rational manner over five years.  The same manner of calculating market-related value is used for all classes of assets, and is applied consistently from year to year.
Puget Energy’s pension and other postretirement benefits income or costs depend on several factors and assumptions, including plan design, timing and amount of cash contributions to the plan, earnings on plan assets, discount rate, expected long-term rate of return, mortality and health care costs trends.  Changes in any of these factors or assumptions will affect the amount of income or expense that Puget Energy records in its financial statements in future years and its projected benefit obligation.  Puget Energy has selected an expected return on plan assets based on a historical analysis of rates of return and Puget Energy’s investment mix, market conditions, inflation and other factors.  As required by merger accounting rules, market-related value was reset to market value effective with the merger.
The discount rates were determined by using market interest rate data and the weighted-average discount rate from Citigroup Pension Liability Index Curve.  The Company also takes into account in determining the discount rate the expected changes in market interest rates and anticipated changes in the duration of the plan liabilities.
Plan Benefits
The expected total benefits to be paid under the next five years and the aggregate total to be paid for the five years thereafter are as follows:
(Dollars in Thousands)	2014			2015			2016			2017			2018			2019-2023
Qualified Pension total benefits	$	40,000		$	40,200		$	40,200		$	41,100		$	42,300		$	226,900
SERP Pension total benefits	3,981			1,985			2,541			1,900			5,177			18,392
Other Benefits total with Medicare Part D subsidy	1,222			1,193			1,242			1,197			1,149			6,276
Other Benefits total without Medicare Part D subsidy	1,604			1,591			1,555			1,519			1,479			6,709
Plan Assets
Plan contributions and the actuarial present value of accumulated plan benefits are prepared based on certain assumptions pertaining to interest rates, inflation rates and employee demographics, all of which are subject to change.  Due to uncertainties inherent in the estimations and assumptions process, changes in these estimates and assumptions in the near term may be material to the financial statements.
The Company has a Retirement Plan Committee that establishes investment policies, objectives and strategies designed to balance expected return with a prudent level of risk.  All changes to the investment policies are reviewed and approved by the Retirement Plan Committee prior to being implemented.
The Retirement Plan Committee invests trust assets with investment managers who have historically achieved above-median long-term investment performance within the risk and asset allocation limits that have been established.  Interim evaluations are routinely performed with the assistance of an outside investment consultant.  To obtain the desired return needed to fund the pension benefit plans, the Retirement Plan Committee has established investment allocation percentages by asset classes as follows:
	Allocation
Asset Class	Minimum	Target	Maximum
Domestic large cap equity	25%	31%	40%
Domestic small cap equity	0%	9%	15%
Non-U.S. equity	10%	25%	30%
Fixed income	15%	25%	30%
Real estate	0%	0%	10%
Absolute return	5%	10%	15%
Cash	0%	0%	5%
Plan Fair Value Measurements
ASC 715, “Compensation – Retirement Benefits” (ASC 715) directs companies to provide additional disclosures about plan assets of a defined benefit pension or other postretirement plan.  The objectives of the disclosures are to disclose the following: (1) how investment allocation decisions are made, including the factors that are pertinent to an understanding of investment policies and strategies; (2) major categories of plan assets; (3) inputs and valuation techniques used to measure the fair value of plan assets; (4) effect of fair value measurements using significant unobservable inputs (Level 3) on changes in plan assets for the period; and (5) significant concentrations of risk within plan assets.
ASC 820 allows the reporting entity, as a practical expedient, to measure the fair value of investments that do not have readily determinable fair values on the basis of the net asset value per share of the investment if the net asset value of the investment is calculated in a matter consistent with ASC 946, “Financial Services – Investment Companies.”  The standard requires disclosures about the nature and risk of the investments and whether the investments are probable of being sold at amounts different from the net asset value per share.
The following table sets forth by level, within the fair value hierarchy, the qualified pension plan as of December 31, 2013 and 2012:
	Recurring Fair Value Measures												Recurring Fair Value Measures
	As of December 31, 2013												As of December 31, 2012
(Dollars in Thousands)	Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
Assets:
Equities:
Non-US equity 1	$	76,188		$	78,816		$	—		$	155,004		$	56,717		$	49,304		$	—		$	106,021
Domestic large cap equity 2	157,874			35,851			—			193,725			136,994			28,890			—			165,884
Domestic small cap equity 3	62,867			—			—			62,867			51,264			—			—			51,264
Total equities	296,929			114,667			—			411,596			244,975			78,194			—			323,169
Tactical asset allocation 4	—			—			—			—			—			26,425			—			26,425
Fixed income securities 5	135,007			—			—			135,007			119,939			—			—			119,939
Absolute return 6	—			—			62,278			62,278			—			—			55,615			55,615
Cash and cash equivalents 7	—			7,054			—			7,054			—			6,019			—			6,019
Subtotal	$	431,936		$	121,721		$	62,278		$	615,935		$	364,914		$	110,638		$	55,615		$	531,167
Net (payable) receivable										(417		)										(173		)
Accrued income										203												189
Total assets										$	615,721											$	531,183
_________________
1	Non – US Equity investments are comprised of a (1) mutual fund; and a (2) commingled fund.  The investment in the mutual fund is valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013.  The investment in the commingled fund is valued at the net asset value per share multiplied by the number of shares held as of December 31, 2013.
2	Domestic large cap equity investments are comprised of (1) common stock, and a (2) commingled fund.  Investments in common stock are valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013.  The investment in the commingled fund is valued at the net asset value per share multiplied by the number of shares held as of December 31, 2013.
3	Domestic small cap equity investments are comprised of (1) common stock and a (2) mutual fund. The investments in common stock are valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013. The investment in the mutual fund is valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013.
4	The tactical asset allocation investment is comprised of a commingled fund, which is valued at the net asset value per share multiplied by the number of shares held as of the measurement date.
5	Fixed income securities consist of a mutual fund.  The investment in the mutual fund is valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013.
6	As of December 31, 2013 absolute return investments consist of two partnerships.  The partnerships are valued using the financial reports as of December 31, 2013.  These investments are a Level 3 under ASC 820 because the significant valuation inputs are primarily internal to the partnerships with little third party involvement.
7	The investment consists of a money market fund, which is valued at the net asset value per share of $1.00 per unit as of December 31, 2013.  The money market fund invests primarily in commercial paper, notes, repurchase agreements, and other evidences of indebtedness which are payable on demand or short-term in nature.
Level 3 Roll-Forward
The following table sets forth a reconciliation of changes in the fair value of the plan’s Level 3 assets:
	As of December 31, 2013									As of December 31, 2012
(Dollars in Thousands)	Partnership			Mutual Funds			Total			Partnership			Mutual Funds			Total
Balance at beginning of year	$	55,614		$	—		$	55,614		$	45,319		$	—		$	45,319
Additional investments	—			—			—			7,021			—			7,021
Distributions	—			—			—			—			—			—
Realized losses on distributions	—			—			—			—			—			—
Unrealized gains relating to instruments still held at the reporting date	6,664			—			6,664			3,274			—			3,274
Transferred out of level 3 1	—			—			—			—			—			—
Balance at end of year	$	62,278		$	—		$	62,278		$	55,614		$	—		$	55,614
_________________
1	The plan had no transfers between level 2 and level 1 during the years ended December 31, 2013 or 2012.
The following table sets forth by level, within the fair value hierarchy, the Other Benefits plan assets which consist of insurance benefits for retired employees, at fair value:
	Recurring Fair Value Measures									Recurring Fair Value Measures
	As of December 31, 2013									As of December 31, 2012
(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
Assets:
Mutual fund 1	$	8,703		$	—		$	8,703		$	7,472		$	—		$	7,472
Cash equivalents 2	—			71			71			—			69			69
Total assets	$	8,703		$	71		$	8,774		$	7,472		$	69		$	7,541
_______________
1	This is a publicly traded balanced mutual fund.  The fund seeks regular income, conservation of principal, and an opportunity for long-term growth of principal and income.  The fair value is determined by taking the number of shares owned by the plan, and multiplying by the market price as of December 31, 2013.
2	This is a money market fund.  The money market fund investments are valued at the net asset value per share of $1.00 per unit as of December 31, 2013.  The money market fund invests primarily in commercial paper, notes, repurchase agreements, and other evidences of indebtedness which are payable on demand or short-term in nature.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	The details of income tax (benefit) expense are as follows:
	Puget Energy	Year Ended December 31,
	(Dollars in Thousands)	2013			2012			2011
	Charged to operating expenses:
	Current:
	Federal	$	—		$	4,268		$	785
	State	—			—			(50		)
	Deferred:
	Federal	122,559			100,701			32,706
	State	(151		)	(244		)	319
	Total income tax expense	$	122,408		$	104,725		$	33,760
	Puget Sound Energy	Year Ended December 31,
	(Dollars in Thousands)	2013			2012			2011
	Charged to operating expenses:
	Current:
	Federal	$	—		$	4,268		$	653
	State	—			—			—
	Deferred:
	Federal	160,886			145,040			76,369
	State	—			—			1,095
	Total income tax expense	$	160,886		$	149,308		$	78,117
	The following reconciliation compares pre-tax book income at the federal statutory rate of 35.0% to the actual income tax expense in the Statements of Income:
	Puget Energy	Year Ended December 31,
	(Dollars in Thousands)	2013			2012			2011
	Income taxes at the statutory rate	$	142,847		$	132,491		$	54,968
	Increase (decrease):
	Production tax credit	(22,414		)	(22,188		)	(23,310		)
	AFUDC excluded from taxable income	(9,406		)	(16,543		)	(22,861		)
	Capitalized interest	7,294			9,757			17,592
	Utility plant differences	9,527			8,674			5,849
	Treasury grant amortization	(7,651		)	(1,007		)	—
	Tenaska gas contract	1			(4,687		)	7,094
	Other - net	2,210			(1,772		)	(5,572		)
	Total income tax expense	$	122,408		$	104,725		$	33,760
	Effective tax rate	30		%	27.7		%	21.5		%
	Puget Sound Energy	Year Ended December 31,
	(Dollars in Thousands)	2013			2012			2011
	Income taxes at the statutory rate	$	180,955		$	176,917		$	98,783
	Increase (decrease):
	Production tax credit	(22,414		)	(22,188		)	(23,310		)
	AFUDC excluded from taxable income	(9,406		)	(16,543		)	(22,861		)
	Capitalized interest	7,294			9,757			17,592
	Utility plant differences	9,527			8,674			5,849
	Treasury grant amortization	(7,651		)	(1,007		)	—
	Tenaska gas contract	1			(4,687		)	7,094
	Other - net	2,580			(1,615		)	(5,030		)
	Total income tax expense	$	160,886		$	149,308		$	78,117
	Effective tax rate	31.1		%	29.5		%	27.7		%
	The Company’s deferred tax liability at December 31, 2013 and 2012 is composed of amounts related to the following types of temporary differences:
	Puget Energy	At December 31,
	(Dollars in Thousands)	2013			2012
	Utility plant and equipment	$	1,625,107		$	1,409,216
	Regulatory asset for income taxes	146,867			119,844
	Fair value of debt instruments	76,991			86,831
	Other deferred tax liabilities	202,189			151,820
	Subtotal deferred tax liabilities	2,051,154			1,767,711
	Net operating loss carryforward	(374,606		)	(298,440		)
	Production tax credit carryforward	(135,531		)	(113,117		)
	Regulatory liability on production tax credit	(71,880		)	(59,811		)
	Fair value of derivative instruments	(7,166		)	(44,835		)
	Other deferred tax assets	(60,970		)	(43,309		)
	Subtotal deferred tax assets	(650,153		)	(559,512		)
Total	$	1,401,001		$	1,208,199
Puget Sound Energy	At December 31,
(Dollars In Thousands)	2013			2012
Utility plant and equipment	$	1,625,107		$	1,409,216
Regulatory asset for income taxes	146,350			119,279
Other deferred tax liabilities	131,977			132,304
Subtotal deferred tax liabilities	1,903,434			1,660,799
Net operating loss carryforward	(173,068		)	(134,513		)
Production tax credit carryforward	(135,531		)	(113,117		)
Regulatory liability on production tax credit	(71,880		)	(59,811		)
Fair value of derivative instruments	(9,988		)	(46,139		)
Other deferred tax assets	(69,175		)	(100,632		)
Subtotal deferred tax assets	(459,642		)	(454,212		)
Total	$	1,443,792		$	1,206,587
The above amounts have been classified in the Consolidated Balance Sheets as follows:
Puget Energy	At December 31
(Dollars in Thousands)	2013			2012
Current deferred taxes	$	(86,004	)	$	(53,437	)
Non-current deferred taxes	1,487,005			1,261,636
Total	$	1,401,001		$	1,208,199
Puget Sound Energy	At December 31
(Dollars in Thousands)	2013			2012
Current deferred taxes	$	(141,058	)	$	(68,015	)
Non-current deferred taxes	1,584,850			1,274,602
Total	$	1,443,792		$	1,206,587
The Company calculates its deferred tax assets and liabilities under ASC 740, “Income Taxes” (ASC 740).  ASC 740 requires recording deferred tax balances, at the currently enacted tax rate, on assets and liabilities that are reported differently for income tax purposes than for financial reporting purposes.  The utilization of deferred tax assets requires sufficient taxable income in future years.  ASC 740 requires a valuation allowance on deferred tax assets when it is more likely than not that the deferred tax assets will not be realized.  The Company’s PTC carryforwards expire from 2026 through 2033.  The Company’s net operating loss carryforwards expire from 2029 through 2033.
For ratemaking purposes, deferred taxes are not provided for certain temporary differences.  PSE has established a regulatory asset for income taxes recoverable through future rates related to those temporary differences for which no deferred taxes have been provided, based on prior and expected future ratemaking treatment.
The Company accounts for uncertain tax position under ASC 740, which clarifies the accounting for uncertainty in income taxes recognized in the financial statements.  ASC 740 requires the use of a two-step approach for recognizing and measuring tax positions taken or expected to be taken in a tax return.  First, a tax position should only be recognized when it is more likely than not, based on technical merits, that the position will be sustained upon challenge by the taxing authorities and taken by management to the court of last resort.  Second, a tax position that meets the recognition threshold should be measured at the largest amount that has a greater than 50.0% likelihood of being sustained.
As of December 31, 2013 and 2012, the Company had no material unrecognized tax benefits.  As a result, no interest or penalties were accrued for unrecognized tax benefits during the year.
For ASC 740 purposes, the Company has open tax years from 2010 through 2013.  The Company classifies interest as interest expense and penalties as other expense in the financial statements.

Litigation

Litigation	12 Months Ended
	Dec. 31, 2013
Litigation Disclosure [Abstract]	'
Litigation	'
	Litigation
	Residential Exchange
	The Northwest Power Act, through the Residential Exchange Program (REP), provides access to the benefits of low-cost federal power for residential and small farm customers of regional utilities, including PSE.  The program is administered by the BPA.  Pursuant to agreements (including settlement agreements) between the BPA and PSE, the BPA has provided payments of REP benefits to PSE, which PSE has passed through to its residential and small farm customers in the form of electricity bill credits.
	In 2007, the United States Court of Appeals for the Ninth Circuit (Ninth Circuit) ruled that REP agreements of the BPA with PSE and a number of other investor-owned utilities were inconsistent with the Northwest Power Act.  Since that time, those investor-owned utilities, including PSE, the BPA and other parties have been involved in ongoing litigation at the Ninth Circuit relating to the amount of REP benefits paid to utilities, including PSE, for the fiscal year 2002 through fiscal year 2011 period and the amount of REP benefits to be paid going forward.
	In July 2011, the BPA, PSE and a number of other parties entered into a settlement agreement (2012 REP Settlement) that by its terms, if upheld in its entirety, would resolve the disputes between BPA and PSE regarding REP benefits paid for fiscal years 2002-2011 and determine REP benefits for fiscal years 2012-2028.  In October 2011, certain other parties challenged BPA decisions with regard to its entering into the 2012 REP Settlement agreement.  On October 28, 2013, the Ninth Circuit issued an order dismissing this challenge to this settlement. In light of the disposition of this challenge, the stay of the other pending Ninth Circuit litigation regarding REP benefits was lifted in January 2014. In the order lifting the stay, petitioners (unless they move to voluntarily dismiss their petitions) and intervenors (unless they move to voluntarily withdraw) were directed to file a statement explaining which issues, if any, remain pending. Such statements are due on or before April 1, 2014. PSE is unable to determine prior to April 1, if this other pending litigation will continue and, if so, what impact these proceedings may have on PSE. However, the Company believes it is unlikely that any unfavorable outcome would have a material adverse effect on PSE because REP benefits received by PSE are passed through directly to REP customers.
	With the Ninth Circuit’s decision affirming the 2012 REP Settlement, PSE will receive approximately $57.0 million plus interests of REP payments owed under a 2008 agreement, which are in addition to scheduled monthly REP benefits received from BPA under the 2012 REP Settlement. These payments will be given back to PSE's residential and small farm customers through a higher residential exchange credit on their bills.
	Colstrip
	PSE has a 50% ownership interest in Colstrip Units 1 and 2, and a 25% interest in Colstrip Units 3 and 4. On March 6, 2013, Sierra Club and Montana Environmental Information Center (MEIC) filed a Clean Air Act citizen suit against all Colstrip owners (including PSE) alleging numerous claims for relief, most which relate to alleged prevention of significant deterioration (PSD) violations. One claim relates to the alleged failure to update the Title V permit to reflect the major modifications alleged in the first 36 claims, another claim alleges that the previous Title V compliance certifications have been incomplete because they did not address the alleged major modifications, and the last claim alleges opacity violations since 2007. The lawsuit was filed in U.S. District of Montana, Billings Division requesting injunctive relief and civil penalties, including a request that the owners remediate environmental damage and that $100,000 of the civil penalties be used for beneficial mitigation projects. This lawsuit followed various Notices of Intent to Sue sent to Colstrip owners (including PSE) from the Sierra Club and the MEIC between July and December 2012.  Discovery in the case has begun, and a prehearing conference took place in July 2013. The case has been bifurcated into separate liability and remedy trials set for March and August 2015, respectively. PSE is litigating the allegations set forth in the notices and cannot at this time predict the outcome of this matter.
	Other Proceedings
	The Company is also involved in litigation relating to claims arising out of its operations in the normal course of business.  The Company has recorded reserves of $1.4 million and $3.4 million relating to these claims as of December 31, 2013 and 2012, respectively.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	For the year ended December 31, 2013, approximately 15.1% of the Company’s energy output was obtained at an average cost of approximately $0.018 per kilowatt hour (kWh) through long-term contracts with three of the Washington Public Utility Districts (PUDs) that own hydroelectric projects on the Columbia River.  The purchase of power from the Columbia River projects is on a pro rata share basis under which the Company pays a proportionate share of the annual debt service, operating and maintenance costs and other expenses associated with each project in proportion to the contractual shares that PSE obtains from that project.  In these instances, PSE’s payments are not contingent upon the projects being operable; therefore, PSE is required to make the payments even if power is not delivered.  These projects are financed through substantially level debt service payments and their annual costs should not vary significantly over the term of the contracts unless additional financing is required to meet the costs of major maintenance, repairs or replacements, or license requirements.  The Company’s share of the costs and the output of the projects is subject to reduction due to various withdrawal rights of the PUDs and others over the contract lives.
	The Company's expenses under these PUD contracts were as follows for the years ended December 31:
	(Dollars in Thousands)				2013			2012			2011
	PUD contract costs				$	63,365		$	70,188		$	81,828
	As of December 31, 2013, the Company purchased portions of the power output of the PUDs' projects as set forth in the following table:
			Company's Current Share of
	(Dollars in Thousands)	Contract	Percent of		Megawatt Capacity		Estimated 2014 Costs			2014 Debt Service Costs			Interest included in 2014 Debt Service Costs			Debt Outstanding
		Expiration	Output
	Chelan County PUD:
	Rock Island Project	2031	25	%	156		$	29,182		$	11,288		$	6,412		$	102,522
	Rocky Reach Project	2031	25	%	325		26,484			8,787			3,563			58,055
	Douglas County PUD:
	Wells Project	2018	29.9	%	251		16,258			8,675			2,678			71,679
	Grant County PUD:
	Priest Rapids Development	2052	0.8	%	9		4,032			2,175			1,274			23,738
	Wanapum Development	2052	0.8	%	9		4,032			2,175			1,274			23,738
	Total				750		$	79,988		$	33,100		$	15,201		$	279,732
	The following table summarizes the Company’s estimated payment obligations for power purchases from the Columbia River projects, contracts with other utilities and contracts with non-utilities.  These contracts have varying terms and may include escalation and termination provisions.
	(Dollars in Thousands)	2014			2015			2016			2017			2018			Thereafter		Total
	Columbia River projects	$	67,094		$	69,401		$	70,924		$	71,091		$	62,477		$	601,448	$	942,435
	Other utilities	17,277			16,718			17,229			10,174			—			—		61,398
	Non-utility contracts	53,928			116,317			150,305			186,948			191,405			1,480,584		2,179,487
	Total	$	138,299		$	202,436		$	238,458		$	268,213		$	253,882		$	2,082,032	$	3,183,320
	Total purchased power contracts provided the Company with approximately 10.7 million, 6.1 million and 8.5 million megawatt hours (MWh) of firm energy at a cost of approximately $348.7 million, $203.1 million and $391.8 million for the years 2013, 2012 and 2011, respectively.
	The Company has natural gas-fired generation facility obligations for natural gas supply amounting to an estimated $118.6 million in 2014.  Longer term agreements for natural gas supply amount to an estimated $318.1 million for 2015 through 2030.
	PSE enters into short-term energy supply contracts to meet its core customer needs.  These contracts are sometimes classified as NPNS, however in most cases recorded at fair value in accordance with ASC 815.  Commitments under these contracts are $32.5 million, $10.8 million and $2.7 million in 2014, 2015 and 2016, respectively.
	Natural Gas Supply Obligations
	The Company has also entered into various firm supply, transportation and storage service contracts in order to ensure adequate availability of natural gas supply for its firm customers.  Many of these contracts, which have remaining terms from less than one year to 31 years, provide that the Company must pay a fixed demand charge each month, regardless of actual usage.  The Company contracts for its long-term natural gas supply on a firm basis, which means the Company has a 100% daily take obligation and the supplier has a 100% daily delivery obligation to ensure service to PSE’s customers and generation requirements.  The Company incurred demand charges in 2013 for firm transportation service and firm storage and peaking service of $160.8 million and $6.6 million, respectively.  The demand charge for firm natural gas supply was immaterial in 2013. The Company incurred demand charges in 2013 for firm transportation and firm storage service for the natural gas supply for its combustion turbines in the amount of $39.5 million, which is included in the total Company demand charges.
	The following table summarizes the Company’s obligations for future demand charges through the primary terms of its existing contracts.  The quantified obligations are based on the FERC and NEB (National Energy Board) currently authorized rates, which are subject to change.
	Demand Charge Obligations	2014			2015			2016			2017			2018			Thereafter		Total
	(Dollars in Thousands)
	Firm transportation service	$	168,936		$	166,452		$	159,899		$	156,205		$	133,281		$	487,739	$	1,272,512
	Firm storage service	6,528			5,337			5,209			5,209			1,407			2,793		26,483
	Total	$	175,464		$	171,789		$	165,108		$	161,414		$	134,688		$	490,532	$	1,298,995
	Service Contracts
	The following table summarizes the Company’s estimated obligations for service contracts through the terms of its existing contracts.
	Service Contract Obligations	2014			2015			2016			2017			2018			Thereafter		Total
	(Dollars in Thousands)
	Energy production service contracts 1	$	26,714		$	33,068		$	15,728		$	5,658		$	4,165		$	27,182	$	112,515
	Automated meter reading system 2	23,443			24,176			13,063			9,558			9,994			80,106		160,340
	Total	$	50,157		$	57,244		$	28,791		$	15,216		$	14,159		$	107,288	$	272,855
	_______________
	1	Energy production service contracts include operations and maintenance contracts on Mint Farm, Wild Horse, Goldendale, Hopkins Ridge, Frederickson 1, Ferndale and Lower Snake River facilities.
	2	Automated meter reading system contractual obligation is the service component of the Landis and Gyr contract.
	For information regarding PSE's environmental remediation obligations, see Note 3 Regulation and Rates.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	On June 1, 2006, PSE entered into a revolving credit facility with Puget Energy in the form of a Demand Promissory Note (Note).  Through the Note, PSE may borrow up to $30.0 million from Puget Energy, subject to approval by Puget Energy.  Under the terms of the Note, PSE pays interest on the outstanding borrowings based on the lowest of the weighted-average interest rate of PSE’s outstanding commercial paper interest rate or PSE’s senior unsecured revolving credit facility.  Absent such borrowings, interest is charged at one-month LIBOR plus 0.25%.  At December 31, 2013 and 2012, the outstanding balance of the Note was $29.6 million and $29.6 million, respectively, and the interest rate was 0.325% and 0.5%, respectively.  The outstanding balance and the related interest under the Note are eliminated by Puget Energy upon consolidation of PSE’s financial statements.  The $30.0 million credit facility with Puget Energy was unaffected by the merger.
	On June 3, 2011, Puget Energy issued $500.0 million of senior secured notes.  Macquarie Capital (USA) Inc. acted as a co-manager and underwriter of this issue.  Net proceeds of $484.0 million from these notes were used to repay a portion of the outstanding $782.0 million term-loan.  Puget Energy’s term-loan and credit facility for funding capital expenditures both were originally scheduled to mature in February 2014, and were syndicated among numerous committed banks and other financial institutions.  One of these banks was Macquarie Bank Limited. On February 10, 2012, Puget Energy terminated the term loan and capital expenditure facility and replaced them with a $1.0 billion revolving credit facility. There are no related parties with commitments under the $1.0 billion revolving credit facility.  Concurrent with the borrowings under the term loan and capital expenditure credit agreements, Puget Energy entered into several interest rate swap instruments to hedge volatility associated with these two loans.  Two of the swap instruments were entered into with Macquarie Bank Limited with a total notional amount of $444.9 million.  On June 3, 2011, Puget Energy settled one of the swaps with a notional amount of $77.4 million. On February 9, 2012, Puget Energy amended and reduced the remaining swap instrument by $67.5 million. On June 18, 2012, Puget Energy terminated and settled the remaining $300.0 million of the swap instrument with Macquarie Bank Limited.

Segment_Information

Segment Information	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment Information	'
	Segment Information
	Puget Energy operates one reportable business segment referred to as the regulated utility segment.  Puget Energy’s regulated utility operation generates, purchases and sells electricity and purchases, transports and sells natural gas.  The service territory of PSE covers approximately 6,000 square miles in the state of Washington. In managing the business, management reviews the consolidated financial statements for Puget Energy and PSE during the year.

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Income (Loss)	12 Months Ended
	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]	'
Accumulated Other Comprehensive Income (Loss)	'
	Accumulated Other Comprehensive Income (Loss)
	The following tables present the changes in the Company’s accumulated other comprehensive income (loss) (AOCI) by component for the years ended December 31, 2013, 2012 and 2011, respectively.
	Puget Energy	Net unrealized gain (loss) on interest rate swaps			Net unrealized gain (loss) and prior service cost on pension plans			Net unrealized gain (loss) on energy derivative instruments
	Changes in AOCI, net of tax
	(Dollars in Thousands)										Total
	Balance at December 31, 2010	$	(40,041	)	$	39,630		$	(2,658	)	$	(3,069	)
	Other comprehensive income (loss) before reclassifications	—			(53,742		)	—			(53,742		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	25,442			(1,083		)	1,545			25,904
	Net current-period other comprehensive income (loss)	25,442			(54,825		)	1,545			(27,838		)
	Balance at December 31, 2011	$	(14,599	)	$	(15,195	)	$	(1,113	)	$	(30,907	)
	Other comprehensive income (loss) before reclassifications	—			(13,574		)	—			(13,574		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	11,577			(296		)	371			11,652
	Net current-period other comprehensive income (loss)	11,577			(13,870		)	371			(1,922		)
	Balance at December 31, 2012	$	(3,022	)	$	(29,065	)	$	(742	)	$	(32,829	)
	Other comprehensive income (loss) before reclassifications	—			76,004			—			76,004
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	2,928			1,575			37			4,540
	Net current-period other comprehensive income (loss)	2,928			77,579			37			80,544
	Balance at December 31, 2013	$	(94	)	$	48,514		$	(705	)	$	47,715
	Puget Sound Energy	Net unrealized gain (loss) and prior service cost on pension plans			Net unrealized gain (loss) on energy derivative instruments			Net unrealized gain (loss) on treasury interest rate swaps
	Changes in AOCI, net of tax
	(Dollars in Thousands)										Total
	Balance at December 31, 2010	$	(115,778	)	$	(34,612	)	$	(7,257	)	$	(157,647	)
	Other comprehensive income (loss) before reclassifications	(59,468		)	—			—			(59,468		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	6,542			21,678			316			28,536
	Net current-period other comprehensive income (loss)	(52,926		)	21,678			316			(30,932		)
	Balance at December 31, 2011	$	(168,704	)	$	(12,934	)	$	(6,941	)	$	(188,579	)
	Other comprehensive income (loss) before reclassifications	(17,049		)	—			—			(17,049		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	9,755			8,358			317			18,430
	Net current-period other comprehensive income (loss)	(7,294		)	8,358			317			1,381
	Balance at December 31, 2012	$	(175,998	)	$	(4,576	)	$	(6,624	)	$	(187,198	)
	Other comprehensive income (loss) before reclassifications	74,969			—			—			74,969
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	13,624			2,549			317			16,490
	Net current-period other comprehensive income (loss)	88,593			2,549			317			91,459
	Balance at December 31, 2013	$	(87,405	)	$	(2,027	)	$	(6,307	)	$	(95,739	)
	Details about these reclassifications out of accumulated other comprehensive income (loss) for the years ended December 31, 2013, 2012 and 2011, respectively, are as follows:
	Puget Energy
	(Dollars in Thousands)
	Details about accumulated other comprehensive income (loss) components	Affected line item in the statement where net income (loss) is presented	Amount reclassified from accumulated
			other comprehensive income (loss)
			2013			2012			2011
	Net unrealized gain (loss) on interest rate swaps:
	Interest rate contracts	Interest expense	$	(4,505	)	$	(17,811	)	$	(39,143	)
		Tax (expense) or benefit	1,577			6,234			13,701
		Net of Tax	$	(2,928	)	$	(11,577	)	$	(25,442	)
	Net unrealized gain (loss) and prior service cost on pension plans:
	Amortization of prior service cost	(a)	1,997			1,980			1,980
	Amortization of net gain (loss)	(a)	(4,420		)	(1,524		)	(314		)
		Total before tax	(2,423		)	456			1,666
		Tax (expense) or benefit	848			(160		)	(583		)
		Net of Tax	$	(1,575	)	$	296		$	1,083
	Net unrealized gain (loss) on energy derivative instruments:
	Commodity contracts: Electric derivatives	Electric generation fuel	—			100			(679		)
		Purchased electricity	(57		)	(671		)	(1,698		)
		Total before tax	(57		)	(571		)	(2,377		)
		Tax (expense) or benefit	20			200			832
		Net of Tax	$	(37	)	$	(371	)	$	(1,545	)
	Total reclassification for the period	Net of Tax	$	(4,540	)	$	(11,652	)	$	(25,904	)
	__________
	(a)	These accumulated other comprehensive income components are included in the computation of net periodic pension cost (see Note 12 for additional details).
	Puget Sound Energy
	(Dollars in Thousands)
	Details about accumulated other comprehensive income (loss) components	Affected line item in the statement where net income (loss) is presented	Amount reclassified from accumulated
			other comprehensive income (loss)
2013			2012			2011
Net unrealized gain (loss) and prior service cost on pension plans:
Amortization of prior service cost	(a)	$	1,559		$	1,245		$	949
Amortization of net gain (loss)	(a)	(22,519		)	(16,203		)	(10,963		)
Amortization of transition obligation	(a)	—			(50		)	(50		)
	Total before tax	(20,960		)	(15,008		)	(10,064		)
	Tax (expense) or benefit	7,336			5,253			3,522
	Net of tax	$	(13,624	)	$	(9,755	)	$	(6,542	)
Net unrealized gain (loss) on energy derivative instruments:
Commodity contracts: Electric derivatives	Electric generation fuel	—			97			(20,625		)
	Purchased electricity	(3,922		)	(12,955		)	(12,726		)
	Total before tax	(3,922		)	(12,858		)	(33,351		)
	Tax (expense) or benefit	1,373			4,500			11,673
	Net of Tax	$	(2,549	)	$	(8,358	)	$	(21,678	)
Net unrealized gain (loss) on treasury interest rate swaps:
Interest rate contracts	Interest expense	(488		)	(488		)	(488		)
	Tax (expense) or benefit	171			171			172
	Net of Tax	$	(317	)	$	(317	)	$	(316	)
Total reclassification for the period	Net of Tax	$	(16,490	)	$	(18,430	)	$	(28,536	)
__________
(a)	These accumulated other comprehensive income components are included in the computation of net periodic pension cost (see Note 12 for additional details).

SUPPLEMENTAL_QUARTERLY_FINANCI

SUPPLEMENTAL QUARTERLY FINANCIAL DATA	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Supplemental Quarterly Financial Data	'
	SUPPLEMENTAL QUARTERLY FINANCIAL DATA
	The following unaudited amounts, in the opinion of the Company, include all adjustments (consisting of normal recurring adjustments) necessary for a fair statement of the results of operations for the interim periods.  Quarterly amounts vary during the year due to the seasonal nature of the utility business.
	Puget Energy	2013 Quarter
	(Unaudited; Dollars in Thousands)	First		Second		Third		Fourth
	Operating revenue	$	999,818	$	642,486	$	598,348	$	946,645
	Operating income	317,735		95,081		100,043		242,301
	Net income	167,475		905		8,540		108,808
		2012 Quarter
	(Unaudited; Dollars in Thousands)	First		Second		Third		Fourth
	Operating revenue	$	1,048,512	$	678,617	$	578,755	$	909,272
	Operating income	209,023		159,876		153,262		193,374
	Net income (loss)	88,480		57,692		46,692		80,957
	Puget Sound Energy	2013 Quarter
	(Unaudited; Dollars in Thousands)	First		Second		Third		Fourth
	Operating revenue	$	999,707	$	642,486	$	598,348	$	946,794
	Operating income	310,587		91,094		96,085		237,808
	Net income	179,938		26,663		26,605		122,923
		2012 Quarter
	(Unaudited; Dollars in Thousands)	First		Second		Third		Fourth
	Operating revenue	$	1,048,512	$	678,617	$	579,611	$	909,519
	Operating income	201,245		153,306		150,007		188,431
	Net income (loss)	112,716		80,872		66,868		95,714

SCHEDULE_I_CONDENSED_FINANCIAL

SCHEDULE I CONDENSED FINANCIAL INFORMATION OF PUGET ENERGY	12 Months Ended
	Dec. 31, 2013
Condensed Financial Information of Parent Company Only Disclosure [Abstract]	'
Schedule I: Condensed Financial Information of Puget Energy	'
	SCHEDULE I:  CONDENSED FINANCIAL INFORMATION OF PUGET ENERGY
	Puget Energy
	Condensed Statements of Income and Comprehensive Income (Loss)
	(Dollars in Thousands)
		Year Ended December 31,
		2013			2012			2011
	Non-utility expense and other	$	(1,255	)	$	(2,040	)	$	(2,280	)
	Other income (deductions):
	Equity in earnings of subsidiary (Note 1)	351,718			365,590			228,288
	Unhedged interest rate swap expense	2,420			(4,288		)	(28,601		)
	Interest income	114			214			215
	Interest expense	(103,372		)	(135,312		)	(131,702		)
	Income taxes	36,103			49,657			57,370
	Net income (loss)	285,728			273,821			123,290
	Comprehensive income (loss)	$	366,272		$	271,899		$	95,452
	See accompanying notes to the consolidated financial statements.
	Puget Energy
	Condensed Balance Sheets
	(Dollars in Thousands)
		December 31,
		2013			2012
	Assets:
	Investment in subsidiaries	$	3,508,460		$	3,490,206
	Other property and investments:
	Goodwill	1,656,513			1,656,513
	Current assets:
	Cash	191			12
	Receivables from affiliates 1	29,605			29,608
	Deferred income taxes	—			2,300
	Total current assets	29,796			31,920
	Long-term assets:
	Deferred income taxes	241,787			166,896
	Other	17,992			20,944
	Total long-term assets	259,779			187,840
	Total assets	$	5,454,548		$	5,366,479
	Capitalization and liabilities:
	Common equity	$	3,679,679		$	3,484,228
	Long-term debt	1,698,964			1,833,959
	Total capitalization	5,378,643			5,318,187
	Current liabilities:
	Account Payable	322			212
	Interest	24,047			26,466
	Deferred income taxes	38,296			—
	Unrealized loss on derivative instruments	6,584			6,571
	Total current liabilities	69,249			33,249
	Long-term liabilities:
	Unrealized loss on derivative instruments	6,656			15,043
	Total long-term liabilities	6,656			15,043
	Commitments and contingencies (Note 3)
	Total capitalization and liabilities	$	5,454,548		$	5,366,479
	_______________
	1	Eliminated in consolidation.
	See accompanying notes to the consolidated financial statements.
	Puget Energy
	Condensed Statements of Cash Flows
	(Dollars in Thousands)
		Year Ended December 31,
		2013			2012			2011
	Operating activities:
	Net income (loss)	$	285,728		$	273,821		$	123,290
	Adjustments to reconcile net income to net cash provided by (used in) operating activities:
	Unrealized gain on derivative instruments	(3,869		)	(12,984		)	33,549
	Deferred income taxes and tax credits - net	(35,872		)	(49,496		)	(57,151		)
Equity in earnings of subsidiary	(351,718		)	(365,590		)	(228,288		)
Other	3,055			11,409			12,837
Dividends received from subsidiaries	410,977			175,625			212,875
Accounts receivable	3			283			618
Income taxes	—			—			14,069
Accounts payable	110			212			—
Accrued interest	(1,299		)	33,842			25,273
Net cash provided by (used in) operating activities	307,115			67,122			137,072
Investing activities:
Investment in subsidiaries	—			—			(287,000		)
(Increase) decrease in loan to subsidiaries	—			400			(7,400		)
Other	(1,120		)	(20,901		)	(16,228		)
Net cash provided by (used in) investing activities	(1,120		)	(20,501		)	(310,628		)
Financing activities:
Dividends paid	(170,821		)	(88,594		)	(117,441		)
Issuance of bond	—			884,000			787,000
Redemption of term-loan and other long-term debt	(135,000		)	(843,000		)	(484,000		)
Issue costs and others	5			(5,239		)	(6,016		)
Net cash provided by (used in) by financing activities	(305,816		)	(52,833		)	179,543
Increase (decrease) in cash	179			(6,212		)	5,987
Cash at beginning of year	12			6,224			237
Cash at end of year	$	191		$	12		$	6,224
See accompanying notes to the consolidated financial statements.
NOTES TO CONDENSED FINANCIAL STATEMENTS
(1) Basis of Presentation
Puget Energy, Inc. (Puget Energy) is an energy services holding company that conducts substantially all of its business operations through its subsidiary. These condensed financial statements and related footnotes have been prepared in accordance with Rule 12-04, Schedule I of Regulation S-X. These financial statements, in which Puget Energy’s subsidiary has been included using the equity method, should be read in conjunction with the consolidated financial statements and notes thereto of Puget Energy included in Part II, Item 8 of this Form 10-K. Puget Energy owns 100% of the common stock of all its subsidiaries.
Equity earnings of subsidiary included earnings from PSE of $356.1 million, $356.2 million and $204.1 million for the years ended December 31, 2013, 2012 and 2011, respectively, and business combination accounting adjustments under ASC 805 recorded at Puget Energy for PSE of $(4.4) million, $9.4 million and $24.2 million for the years ended December 31, 2013, 2012 and 2011, respectively. Investment in subsidiaries includes Puget Energy business combination accounting adjustments under ASC 805 that are recorded at Puget Energy.
The Company has revised its condensed statements of net income and comprehensive income (loss) for the years ended December 31, 2012 and 2011 for errors in recording comprehensive income of PSE. The Company also revised its condensed statements of cash flows which resulted in adjustments between cash provided by operating activities and cash used investing activities to reflect payments made on unhedged interest rate swap agreements that were previously classified as an operating activity. These adjustments are not considered material, individually or in the aggregate, to the previously issued condensed statements of income and comprehensive income (loss) and condensed statements of cash flows. The table below illustrates the effects of these adjustments on the condensed statements of income and comprehensive income (loss) and condensed statement of cash flows for those line items affected.
Condensed Statements of Income and Comprehensive Income (Loss)	As Reported							As Revised
	Year Ended December 31,							Year Ended December 31,
(Dollars in Thousands)	2012			2011				2012			2011
Comprehensive income (loss)	$	285,398		$	148,733			$	271,899		$	95,452
Condensed Statements of Cash Flows	As Reported							As Revised
	Year Ended December 31,							Year Ended December 31,
(Dollars in Thousands)	2012			2011				2012			2011
Net cash provided by (used in) operating activities	$	46,221		$	120,844			$	67,122		$	137,072
Net cash provided by (used in) investing activities	$	400		$	(294,400	)		$	(20,501	)	$	(310,628	)
(2) Debt
For information concerning Puget Energy’s long-term debt obligations, see Note 6, Long-Term Debt, to the consolidated financial statements of Puget Energy.
(3) Commitments and Contingencies
For information concerning Puget Energy’s material contingencies and guarantees, see Note 15, Commitments and Contingencies, to the consolidated financial statements of Puget Energy.

SCHEDULE_II_VALUATION_AND_QUAL

SCHEDULE II VALUATION AND QUALIFYING ACCOUNTS AND RESERVES	12 Months Ended
	Dec. 31, 2013
Valuation and Qualifying Accounts [Abstract]	'
Schedule II: Valuation and Qualifying Accounts and Reserves	'
	SCHEDULE II: VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
	Puget Energy	Balance At		Additions		Deductions		Balance
	(Dollars in Thousands)	Beginning of		Charged to				At End
		Period		Costs and				Of Period
				Expenses
	Year Ended December 31, 2013
	Accounts deducted from assets on balance sheet:
	Allowance for doubtful accounts receivable	$	9,932	$	26,330	$	28,877	$	7,385
	Year Ended December 31, 2012
	Accounts deducted from assets on balance sheet:
	Allowance for doubtful accounts receivable	$	8,495	$	21,567	$	20,130	$	9,932
	Year Ended December 31, 2011
	Accounts deducted from assets on balance sheet:
	Allowance for doubtful accounts receivable	$	9,784	$	18,449	$	19,738	$	8,495
	Puget Sound Energy	Balance At		Additions		Deductions		Balance
	(Dollars in Thousands)	Beginning of		Charged to				At End
		Period		Costs and				Of Period
				Expenses
	Year Ended December 31, 2013
	Accounts deducted from assets on balance sheet:
	Allowance for doubtful accounts receivable	$	9,932	$	26,330	$	28,877	$	7,385
	Year Ended December 31, 2012
	Accounts deducted from assets on balance sheet:
	Allowance for doubtful accounts receivable	$	8,495	$	21,567	$	20,130	$	9,932
	Year Ended December 31, 2011
	Accounts deducted from assets on balance sheet:
	Allowance for doubtful accounts receivable	$	9,784	$	18,449	$	19,738	$	8,495

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	Puget Energy, Inc. (Puget Energy) is an energy services holding company that owns Puget Sound Energy, Inc. (PSE).  PSE is a public utility incorporated in the state of Washington that furnishes electric and natural gas services in a territory covering 6,000 square miles, primarily in the Puget Sound region.  On February 6, 2009, Puget Holdings LLC (Puget Holdings), owned by a consortium of long-term infrastructure investors, completed its merger with Puget Energy (the merger).  As a result of the merger, all of Puget Energy’s common stock is indirectly owned by Puget Holdings.  The acquisition of Puget Energy was accounted for in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 805, “Business Combinations” (ASC 805), as of the date of the merger.  ASC 805 requires the acquirer to recognize and measure identifiable assets acquired and liabilities assumed at fair value as of the merger date.
	The consolidated financial statements of Puget Energy reflect the accounts of Puget Energy and its subsidiary, PSE.  PSE’s consolidated financial statements include the accounts of PSE and its subsidiary.  Puget Energy and PSE are collectively referred to herein as “the Company.”  The consolidated financial statements are presented after elimination of all significant intercompany items and transactions.  PSE’s consolidated financial statements continue to be accounted for on a historical basis and PSE’s financial statements do not include any ASC 805 purchase accounting adjustments.  The preparation of financial statements in conformity with U.S. Generally Accepted Accounting Principles (GAAP) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period.  Actual results could differ from those estimates.
	Certain prior year amounts have been corrected to conform to the current year presentation. In addition, at December 31, 2013, PSE revised 2012 credit balances in customer’s accounts receivable to accounts payable in the amount of $33.7 million in order to correct errors included in the December 31, 2012 balances. The Company believes these amounts are not material to the financial statements.
Utility Plant	'
	Utility Plant
	Puget Energy and PSE capitalize, at original cost, additions to utility plant, including renewals and betterments.  Costs include indirect costs such as engineering, supervision, certain taxes, pension and other employee benefits and an Allowance For Funds Used During Construction (AFUDC).  Replacements of minor items of property are included in maintenance expense. When the utility plant is retired and removed from service, the original cost of the property is charged to accumulated depreciation and costs associated with removal of the property, less salvage, are charged to the cost of removal regulatory liability.
	Planned Major Maintenance
	Planned major maintenance is an activity that typically occurs when PSE overhauls or substantially upgrades various systems and equipment on its natural gas fired combustion turbines on a scheduled basis. Costs related to planned major maintenance, in excess of $0.5 million, are deferred and amortized to the next scheduled major maintenance. This accounting method also follows the Washington Utilities and Transportation Commission (Washington Commission) regulatory treatment related to these generating facilities.
Non-Utility Property, Plant and Equipment	'Non-Utility Property, Plant and EquipmentFor PSE, the costs of other property, plant and equipment are stated at historical cost.  Expenditures for refurbishment and improvements that significantly add to productive capacity or extend useful life of an asset are capitalized.  Replacement of minor items are expensed on a current basis.  Gains and losses on assets sold or retired are reflected in earnings.
Depreciation and Amortization	'Depreciation and AmortizationFor financial statement purposes, the Company provides for depreciation and amortization on a straight-line basis.  Amortization is recorded for intangibles such as regulatory assets and liabilities, computer software and franchises.  The depreciation of vehicles and equipment is allocated to the asset and expense accounts based on usage.  The annual depreciation provision stated as a percent of a depreciable electric utility plant was 2.8%, 2.9% and 2.7% in 2013, 2012 and 2011, respectively; depreciable gas utility plant was 3.4%, 3.4% and 3.5% in 2013, 2012 and 2011, respectively; and depreciable common utility plant was 11.4%, 11.6% and 11.3% in 2013, 2012 and 2011, respectively.  Depreciation on other property, plant and equipment is calculated primarily on a straight-line basis over the useful lives of the assets.  The cost of removal is collected from PSE’s customers through depreciation expense and any excess is recorded as a regulatory liability.
Goodwill	'
	Goodwill
	On February 6, 2009, Puget Holdings completed its merger with Puget Energy.  Puget Energy remeasured the carrying amount of all its assets and liabilities to fair value, which resulted in recognition of approximately $1.7 billion in goodwill.  ASC 350, “Intangibles - Goodwill and Other” (ASC 350), requires that goodwill be tested for impairment at the reporting unit level on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value.  These events or circumstances could include a significant change in the Company’s business or regulatory outlook, legal factors, a sale or disposition of a significant portion of a reporting unit or significant changes in the financial markets which could influence the Company’s access to capital and interest rates.  Application of the goodwill impairment test requires judgment, including the identification of reporting units, assignment of assets and liabilities to reporting units, assignment of goodwill to reporting units and the determination of the fair value of the reporting units.  Management has determined Puget Energy has only one reporting unit.
	The goodwill recorded by Puget Energy represents the potential long-term return to the Company’s investors.  Goodwill is tested for impairment annually using a two-step process.  The first step compares the carrying amount of the reporting unit with its fair value, with a carrying value higher than fair value indicating potential impairment.  If the first step test fails, the second step is performed.  This would entail a full valuation of Puget Energy’s assets and liabilities and comparing the valuation to its carrying amounts, with the aggregate difference indicating the amount of impairment.  Goodwill of a reporting unit is required to be tested for impairment on an interim basis if an event occurs or circumstances change that would cause the fair value of a reporting unit to fall below its carrying amount.
	Puget Energy conducted its annual impairment test in 2013 using an October 1, 2013 measurement date.  The fair value of Puget Energy’s reporting unit was estimated using both discounted cash flow and market approach.  Such approaches are considered methodologies that market participants would use.  This analysis requires significant judgments, including estimation of future cash flows, which is dependent on internal forecasts, estimation of long-term rate of growth for Puget Energy business, estimation of the useful life over which cash flows will occur, the selection of utility holding companies determined to be comparable to Puget Energy and determination of an appropriate weighted-average cost of capital or discount rate.  The market approach estimates the fair value of the business based on market prices of stocks of comparable companies engaged in the same or similar lines of business.  In addition, indications of market value are estimated by deriving multiples of equity or invested capital to various measures of revenue, earnings or cash flow.  Changes in these estimates and or assumptions could materially affect the determination of fair value and goodwill impairment of the reporting unit.  Based on the test performed, management has determined that there was no indication of impairment of Puget Energy’s goodwill as of October 1, 2013.  There were no events or circumstances from the date of the assessment through December 31, 2013 that would impact management’s conclusion.
Cash and Cash Equivalents	'
	Cash and Cash Equivalents
	Cash and cash equivalents consist of demand bank deposits and short-term highly liquid investments with original maturities of three months or less at the time of purchase.  The cash and cash equivalents balance at Puget Energy was $44.3 million and $135.5 million as of December 31, 2013 and 2012, respectively.  The 2013 and 2012 balance consisted of cash equivalents, which are reported at cost and approximate fair value, and were $2.6 million and $107.6 million, respectively.
Materials and Supplies	'
	Materials and Supplies
	Materials and supplies are used primarily in the operation and maintenance of electric and natural gas distribution and transmission systems as well as spare parts for combustion turbines used for the generation of electricity.  Puget Energy and PSE record these items at weighted-average cost.
Fuel and Gas Inventory	'
	Fuel and Gas Inventory
	Fuel and gas inventory is used in the generation of electricity and for future sales to the Company’s natural gas customers.  Fuel inventory consists of coal, diesel and natural gas used for generation.  Gas inventory consists of natural gas and liquefied natural gas (LNG) held in storage for future sales.  Puget Energy and PSE record these items at the lower of cost or market value using the weighted-average cost method.
Regulatory Assets and Liabilities	'Regulatory Assets and LiabilitiesPSE accounts for its regulated operations in accordance with ASC 980 “Regulated Operations” (ASC 980).  ASC 980 requires PSE to defer certain costs that would otherwise be charged to expense, if it is probable that future rates will permit recovery of such costs.  It similarly requires deferral of revenues or gains and losses that are expected to be returned to customers in the future.  Accounting under ASC 980 is appropriate as long as rates are established by or subject to approval by independent third-party regulators; rates are designed to recover the specific enterprise’s cost of service; and in view of demand for service, it is reasonable to assume that rates set at levels that will recover costs can be charged to and collected from customers.  In most cases, PSE classifies regulatory assets and liabilities as long-term assets or liabilities due to the length of the amortization.  The exception is the Purchased Gas Adjustment (PGA) which can be a current asset or current liability.
Allowance for Funds Used During Construction	'
	Allowance for Funds Used During Construction
	AFUDC represents the cost of both the debt and equity funds used to finance utility plant additions during the construction period.  The amount of AFUDC recorded in each accounting period varies depending principally upon the level of construction work in progress and the AFUDC rate used.  AFUDC is capitalized as a part of the cost of utility plant and is credited to interest expense and as a non-cash item to other income.  Cash inflow related to AFUDC does not occur until these charges are reflected in rates.
	The AFUDC rates authorized by the Washington Commission for natural gas and electric utility plant additions based on the effective dates are as follows:
	Effective Date	Washington Commission
		AFUDC Rates
	July 1, 2013 - present	7.77	%
	May 14, 2012 - June 30, 2013	7.8
	April 8, 2010 - May 13, 2012	8.1
	The Washington Commission authorized the Company to calculate AFUDC using its allowed rate of return.  To the extent amounts calculated using this rate exceed the AFUDC calculated rate using the Federal Energy Regulatory Commission (FERC) formula, PSE capitalizes the excess as a deferred asset, crediting other income.  The deferred asset is being amortized over the average useful life of PSE’s non-project electric utility plant which is approximately 30 years.
Revenue Recognition	'
	Revenue Recognition
	Operating utility revenue is recognized when the basis of services is rendered, which includes estimated unbilled revenue, in accordance with ASC 605, “Revenue Recognition” (ASC 605).  PSE's estimate of unbilled revenue is based on a calculation using meter readings from its automated meter reading (AMR) system. The estimate calculates unbilled usage at the end of each month as the difference between the customer meter readings on the last day of the month and the last customer meter readings billed. The unbilled usage is then priced at published rates for each schedule to estimate the unbilled revenues by customer.
	Non-utility subsidiaries recognize revenue when services are performed or upon the sale of assets.  Revenue from retail sales is billed based on tariff rates approved by the Washington Commission.  Sales of Renewable Energy Credits (RECs) are deferred as a regulatory liability.
	PSE collected Washington State excise taxes (which are a component of general retail customer rates) and municipal taxes totaling $243.9 million, $244.2 million and $252.5 million for 2013, 2012 and 2011, respectively.  The Company reports the collection of such taxes on a gross basis in operating revenue and as expense in taxes other than income taxes in the accompanying consolidated statements of income.
	Beginning July 1, 2013, PSE's electric and gas operations contain a revenue decoupling mechanism under which PSE's actual energy delivery revenues related to electric transmission and distribution, gas operations and general administrative costs are compared with authorized revenues allowed under the mechanism. Any differences are deferred to a regulatory asset for under recovery or regulatory liability for over recovery. Revenues associated with power costs under the Power Cost Adjustment (PCA) mechanism and PGA rates are excluded from the decoupling mechanism.
Allowance for Doubtful Accounts	'Allowance for Doubtful AccountsAllowance for doubtful accounts are provided for electric and natural gas customer accounts based upon a historical experience rate of write-offs of energy accounts receivable along with information on future economic outlook.  The allowance account is adjusted monthly for this experience rate.   The allowance account is maintained until either receipt of payment or the likelihood of collection is considered remote at which time the allowance account and corresponding receivable balance are written off.The Company’s allowance for doubtful accounts at December 31, 2013 and 2012 was $7.4 million and $9.9 million, respectively.
Self Insurance	'
	Self-Insurance
	PSE currently has no insurance coverage for storm damage and recent environmental contamination occurring on PSE-owned property.  PSE is self-insured for a portion of the risk associated with comprehensive liability, workers’ compensation claims and catastrophic property losses other than those which are storm related.  The Washington Commission has approved the deferral of certain uninsured qualifying storm damage costs that exceed $8.0 million which will be requested for collection in future rates.  Additionally, costs may only be deferred if the outage meets the Institute of Electrical and Electronics Engineers (IEEE) outage criteria for system average interruption duration index.
Federal Income Taxes	'
	Federal Income Taxes
	For presentation in Puget Energy and PSE’s separate financial statements, income taxes are allocated to the subsidiaries on the basis of separate company computations of tax, modified by allocating certain consolidated group limitations which are attributed to the separate company.  Taxes payable or receivable are settled with Puget Holdings.
Natural Gas Off System Sales and Capacity Release	'
	Natural Gas Off-System Sales and Capacity Release
	PSE contracts for firm natural gas supplies and holds firm transportation and storage capacity sufficient to meet the expected peak winter demand for natural gas by its firm customers.  Due to the variability in weather, winter peaking consumption of natural gas by most of its customers and other factors, PSE holds contractual rights to natural gas supplies and transportation and storage capacity in excess of its average annual requirements to serve firm customers on its distribution system.  For much of the year, there is excess capacity available for third-party natural gas sales, exchanges and capacity releases.  PSE sells excess natural gas supplies, enters into natural gas supply exchanges with third parties outside of its distribution area and releases to third parties excess interstate natural gas pipeline capacity and natural gas storage rights on a short-term basis to mitigate the costs of firm transportation and storage capacity for its core natural gas customers.  The proceeds from such activities, net of transactional costs, are accounted for as reductions in the cost of purchased natural gas and passed on to customers through the PGA mechanism, with no direct impact on net income.  As a result, PSE nets the sales revenue and associated cost of sales for these transactions in purchased natural gas.
Non-Core Gas Sales	'
	Non-Core Gas Sales
	As part of the Company’s electric operations, PSE provides natural gas to its gas-fired generation facilities.  The projected volume of natural gas for power is relative to the price of natural gas.  Based on the market prices for natural gas, PSE may use the gas it has already purchased to generate power or PSE may sell the already purchased natural gas.  The net proceeds from selling natural gas, previously purchased for power generation, are accounted for in other electric operating revenue and are included in the PCA mechanism.
Production Tax Credit	'
	Production Tax Credit
	Production Tax Credits (PTCs) represent federal income tax incentives available to taxpayers that generate energy from qualifying renewable sources.  Prior to July 1, 2010, PSE passed the benefit of the PTCs to customers as the benefits were generated.  After July 1, 2010, PSE records the benefit of the PTCs as a regulatory liability until such time as PSE utilizes the tax credit on its tax return. Once utilized, PSE will pass the benefit to customers.
Accounting for Derivatives	'
	Accounting for Derivatives
	ASC 815 requires that all contracts considered to be derivative instruments be recorded on the balance sheet at their fair value unless the contracts qualify for an exception.  PSE enters into derivative contracts to manage its energy resource portfolio and interest rate exposure including forward physical and financial contracts and swaps.  Some of PSE’s physical electric supply contracts qualify for the Normal Purchase Normal Sale (NPNS) exception to derivative accounting rules.  PSE may enter into financial fixed price contracts to economically hedge the variability of certain index-based contracts.  Those contracts that do not meet the NPNS exception are marked-to-market to current earnings in the statements of income, subject to deferral under ASC 980, for energy related derivatives due to the PCA mechanism and PGA mechanism.
	Puget Energy and PSE elected to de-designate all energy related derivative contracts previously recorded as cash flow hedges for the purpose of simplifying its financial reporting in 2009.  The contracts that were de-designated related to physical electric supply contracts and natural gas swap contracts used to fix the price of natural gas for electric generation.  For these contracts and for contracts initiated after such date, all mark-to-market adjustments are recognized through earnings.  The amount previously recorded in accumulated other comprehensive income (OCI) is transferred to earnings in the same period or periods during which the hedged transaction affects earnings or sooner if management determines that the forecasted transaction is probable of not occurring.  As a result, the Company will continue to experience the earnings impact of these reversals from OCI in future periods.
	The Company may enter into swap instruments or other financial derivative instruments to manage the interest rate risk associated with its long-term debt financing and debt instruments.  As of December 31, 2013, Puget Energy has interest rate swap contracts outstanding related to its long-term debt.  For additional information, see Note 9 Accounting for Derivative Instruments and Hedging Activities.
Fair Value Measurements of Derivatives	'
	Fair Value Measurements of Derivatives
	ASC 820, “Fair Value Measurements and Disclosures” (ASC 820), defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price).  However, as permitted under ASC 820, the Company utilizes a mid-market pricing convention (the mid-point price between bid and ask prices) as a practical expedient for valuing the majority of its assets and liabilities measured and reported at fair value.  The Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique.  These inputs can be readily observable, market corroborated or generally unobservable.  The Company primarily applies the market approach for recurring fair value measurements as it believes that the approach is used by market participants for these types of assets and liabilities.  Accordingly, the Company utilizes valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.
	The Company values derivative instruments based on daily quoted prices from an independent external pricing service.  When external quoted market prices are not available for derivative contracts, the Company uses a valuation model that uses volatility assumptions relating to future energy prices based on specific energy markets and utilizes externally available forward market price curves.  All derivative instruments are sensitive to market price fluctuations that can occur on a daily basis.  For additional information, see Note 10 Fair Value Measurements.
Debt Related Costs	'
	Debt Related Costs
	Debt premiums, discounts, expenses and amounts received or incurred to settle hedges are amortized over the life of the related debt for the Company.  The premiums and costs associated with reacquired debt are deferred and amortized over the life of the related new issuance, in accordance with ratemaking treatment for PSE.
Statements of Cash Flows	'
	Statements of Cash Flows
	The Company has refinancing transactions that do not result in an actual exchange of cash. For these transactions, the Company evaluates if the non-exchange of cash is for convenience purposes and if so, the Company considers the transaction as if it had constructively received and disbursed the cash and presents the transaction as gross on the financing section of the statements of cash flows.
	PSE funds cash dividends to pay the shareholder of Puget Energy.
	The following non-cash investing and financing activities have occurred at the Company:
	•	PSE did not incur any capital lease obligations in 2013 or 2012. PSE incurred capital lease obligations of $37.9 million for AMR modules and network in 2011.
	The Company revised its Consolidated Statement of Cash Flows due to an immaterial error. Revisions were made in the second quarter ended June 30, 2013 on the Company's Consolidated Statement of Cash Flows to reflect energy efficiency expenditures as operating cash outflows instead of investing cash outflows. The Company determined energy efficiency expenditures should have been classified as operating activities instead of investing activities. These revisions decreased net cash provided by operating activities and decreased net cash used by investing activities. The revision does not affect the net change in cash and cash equivalents for any of the periods, and has no effect on the Company's Consolidated Statements of Income, Consolidated Statements of Comprehensive Income, Consolidated Balance Sheets, and Consolidated Statement of Common Shareholder's Equity. The Company has evaluated the effects of these errors and concluded that none of them are material to any of the Company's previously issued quarterly or annual Financial Statements. Nevertheless, the Company has elected to revise the Consolidated Statement of Cash Flows in this report to correct for the effect of these errors and properly reflect the revised values.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Entity Information [Line Items]	'
Schedule of Authorized AFUDC Rates	'
	The AFUDC rates authorized by the Washington Commission for natural gas and electric utility plant additions based on the effective dates are as follows:
	Effective Date	Washington Commission
		AFUDC Rates
	July 1, 2013 - present	7.77	%
	May 14, 2012 - June 30, 2013	7.8
	April 8, 2010 - May 13, 2012	8.1
Schedule of Error Corrections and Prior Period Adjustments [Table Text Block]	'
	The amounts on prior period Consolidated Statements of Cash Flows that have been revised are summarized below:
		As Reported							As Revised
	Puget Energy	Year Ended December 31,							Year Ended December 31,
	(Dollars in Thousands)	2012			2011				2012			2011
	Operating Activities:
	Regulatory Assets	$	(64,368	)	$	30,232			$	(170,374	)	$	(64,173	)
	Net Cash Provided by Operating Activities	$	888,691		$	1,010,328			$	782,685		$	915,923
	Investing Activities:
	Energy Efficiency Expenditures	$	(106,006	)	$	(94,405	)		$	—		$	—
	Net Cash Used in Investing Activities	$	(798,976	)	$	(1,076,815	)		$	(692,970	)	$	(982,410	)
		As Reported							As Revised
	Puget Sound Energy	Year Ended December 31,							Year Ended December 31,
	(Dollars in Thousands)	2012			2011				2012			2011
	Operating Activities:
	Regulatory Assets	$	(64,368	)	$	29,271			$	(170,374	)	$	(65,134	)
	Net Cash Provided by Operating Activities	$	903,888		$	903,422			$	797,882		$	809,017
	Investing Activities:
	Energy Efficiency Expenditures	$	(106,006	)	$	(94,405	)		$	—		$	—
	Net Cash Used in Investing Activities	$	(778,075	)	$	(1,060,588	)		$	(672,069	)	$	(966,183	)
Schedule of Accumulated Other Comprehensive Income (Loss)	'
	The following tables set forth the components of the Company’s accumulated other comprehensive income (loss) at:
	Puget Energy	December 31,
	(Dollars in Thousands)	2013			2012
	Net unrealized loss on energy derivative instruments	$	(705	)	$	(742	)
	Net unrealized loss on interest rate swaps	(94		)	(3,022		)
	Net unrealized loss and prior service cost on pension plans	48,514			(29,065		)
	Total Puget Energy, net of tax	$	47,715		$	(32,829	)
	Puget Sound Energy	December 31,
	(Dollars in Thousands)	2013			2012
	Net unrealized loss on energy derivative instruments	$	(2,027	)	$	(4,576	)
	Net unrealized loss on treasury interest rate swaps	(6,307		)	(6,624		)
	Net unrealized loss and prior service cost on pension plans	(87,405		)	(175,998		)
	Total PSE, net of tax	$	(95,739	)	$	(187,198	)
	The following tables present the changes in the Company’s accumulated other comprehensive income (loss) (AOCI) by component for the years ended December 31, 2013, 2012 and 2011, respectively.
	Puget Energy	Net unrealized gain (loss) on interest rate swaps			Net unrealized gain (loss) and prior service cost on pension plans			Net unrealized gain (loss) on energy derivative instruments
	Changes in AOCI, net of tax
	(Dollars in Thousands)										Total
	Balance at December 31, 2010	$	(40,041	)	$	39,630		$	(2,658	)	$	(3,069	)
	Other comprehensive income (loss) before reclassifications	—			(53,742		)	—			(53,742		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	25,442			(1,083		)	1,545			25,904
	Net current-period other comprehensive income (loss)	25,442			(54,825		)	1,545			(27,838		)
	Balance at December 31, 2011	$	(14,599	)	$	(15,195	)	$	(1,113	)	$	(30,907	)
	Other comprehensive income (loss) before reclassifications	—			(13,574		)	—			(13,574		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	11,577			(296		)	371			11,652
	Net current-period other comprehensive income (loss)	11,577			(13,870		)	371			(1,922		)
	Balance at December 31, 2012	$	(3,022	)	$	(29,065	)	$	(742	)	$	(32,829	)
	Other comprehensive income (loss) before reclassifications	—			76,004			—			76,004
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	2,928			1,575			37			4,540
	Net current-period other comprehensive income (loss)	2,928			77,579			37			80,544
	Balance at December 31, 2013	$	(94	)	$	48,514		$	(705	)	$	47,715
	Puget Sound Energy	Net unrealized gain (loss) and prior service cost on pension plans			Net unrealized gain (loss) on energy derivative instruments			Net unrealized gain (loss) on treasury interest rate swaps
	Changes in AOCI, net of tax
	(Dollars in Thousands)										Total
	Balance at December 31, 2010	$	(115,778	)	$	(34,612	)	$	(7,257	)	$	(157,647	)
	Other comprehensive income (loss) before reclassifications	(59,468		)	—			—			(59,468		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	6,542			21,678			316			28,536
	Net current-period other comprehensive income (loss)	(52,926		)	21,678			316			(30,932		)
	Balance at December 31, 2011	$	(168,704	)	$	(12,934	)	$	(6,941	)	$	(188,579	)
	Other comprehensive income (loss) before reclassifications	(17,049		)	—			—			(17,049		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	9,755			8,358			317			18,430
	Net current-period other comprehensive income (loss)	(7,294		)	8,358			317			1,381
	Balance at December 31, 2012	$	(175,998	)	$	(4,576	)	$	(6,624	)	$	(187,198	)
	Other comprehensive income (loss) before reclassifications	74,969			—			—			74,969
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	13,624			2,549			317			16,490
	Net current-period other comprehensive income (loss)	88,593			2,549			317			91,459
	Balance at December 31, 2013	$	(87,405	)	$	(2,027	)	$	(6,307	)	$	(95,739	)

Regulation_and_Rates_Tables

Regulation and Rates (Tables)	12 Months Ended
	Dec. 31, 2013
Regulation and Rates [Line Items]	'
Schedule of Allowed Return on the Net Regulatory Assets and Liabilities	'
	Below is a chart with the allowed return on the net regulatory assets and liabilities and the associated time periods:
	Period	Rate of Return	After-Tax Return
	July 1, 2013 - present	7.77%	6.69%
	May 14, 2012 - June 30, 2013	7.8	6.71
	April 8, 2010 - May 13, 2012	8.1	6.9
Schedule of Net Regulatory Assets and Liabilities	'
	The net regulatory assets and liabilities at December 31, 2013 and 2012 included the following:
	Puget Sound Energy	Remaining Amortization Period	December 31,
	(Dollars in Thousands)		2013			2012
	PGA deferral of unrealized losses on derivative instruments	(a)	$	27,555		$	95,953
	Chelan PUD contract initiation	17.8 years	126,404			133,492
	Storm damage costs electric	1 to 5 years	116,328			131,904
	Environmental remediation	(a)	57,342			66,402
	Baker Dam licensing operating and maintenance costs	45 years	57,270			57,644
	Snoqualmie licensing operating and maintenance costs	31 years	10,881			7,816
	Colstrip common property	10.5 years	7,479			8,195
	Deferred income taxes	(a)	146,350			119,279
	Deferred Washington Commission AFUDC	Varies up to 36 years	55,495			55,896
	Energy conservation costs	1 to 2 years	35,987			26,940
	Unamortized loss on reacquired debt	1 to 22.5 years	37,832			31,399
	White River relicensing and other costs	(a)	28,190			29,654
	Mint Farm ownership and operating costs	11.3 years	22,320			24,321
	Investment in Bonneville Exchange power contract	3.5 years	12,343			15,870
	Ferndale	5.8 years	22,811			1,789
	Lower Snake River	2.3 to 23.3 years	92,924			126,887
	Snoqualmie	5.8 years	8,009			—
	Property tax tracker	(a)	22,134			—
	Various other regulatory assets	Varies	8,078			2,782
	Total PSE regulatory assets		$	895,732		$	936,223
	Cost of removal	(b)	$	(269,536	)	$	(239,243	)
	Production tax credits	(c)	(93,618		)	(93,618		)
	PGA payable	1 year	(5,938		)	(32,587		)
	PCA mechanism	(a)	(5,345		)	—
	Decoupling over-collection	(a)	(20,535		)	—
	Summit purchase option buy-out	6.8 years	(10,763		)	(12,338		)
	Deferred gain on Jefferson County sale	(a)	(60,844		)	—
	Deferred credit on Biogas sale	1 year	(10,908		)	—
	Deferred credit on gas pipeline capacity	Varies up to 4.8 years	(4,508		)	(6,213		)
	Renewable energy credits	(a)	(5,820		)	(11,341		)
	Treasury grants	6 to 9 years	(203,889		)	(225,573		)
	Various other regulatory liabilities	Up to 4 years	(5,755		)	(7,998		)
	Total PSE regulatory liabilities		$	(697,459	)	$	(628,911	)
	PSE net regulatory assets (liabilities)		$	198,273		$	307,312
	_______________
	(a)	Amortization periods vary depending on timing of underlying transactions or awaiting regulatory approval in a future Washington Commission rate proceeding.
	(b)	The balance is dependent upon the cost of removal of underlying assets and the life of utility plant.
	(c)	Amortization will begin once PTCs are utilized by PSE on its tax return.
	Puget Energy	Remaining Amortization Period	December 31,
	(Dollars in Thousands)		2013			2012
	Total PSE regulatory assets	(a)	$	895,732		$	936,223
	Puget Energy acquisition adjustments:
	Regulatory assets related to power contracts	1 to 23 years	33,753			37,655
	Various other regulatory assets	Varies	517			3,179
	Total Puget Energy regulatory assets		$	930,002		$	977,057
	Total PSE regulatory liabilities	(a)	$	(697,459	)	$	(628,911	)
	Puget Energy acquisition adjustments:
	Regulatory liabilities related to power contracts	1 to 38 years	(443,065		)	(507,009		)
	Various other regulatory liabilities	Varies	(2,884		)	(4,373		)
	Total Puget Energy regulatory liabilities		$	(1,143,408	)	$	(1,140,293	)
	Puget Energy net regulatory asset (liabilities)		$	(213,406	)	$	(163,236	)
	_______________
	(a)	Puget Energy’s regulatory assets and liabilities include purchase accounting adjustments under ASC 805 as a result of the merger.
Schedule of Graduated Scale of Rate Adjustment Mechanisms	'
	The graduated scale is as follows:
	Annual Power Cost Variability	Customers’ Share	Company’s Share
	+/- $20 million	0%	100%
	+/- $20 million - $40 million	50%	50%
	+/- $40 million - $120 million	90%	10%
	+/- $120 + million	95%	5%
Electric	'
Regulation and Rates [Line Items]	'
Schedule of Effects on Annual Revenue Due to Approved Rate Adjustments	'
	The following table sets forth electric rate adjustments approved by the Washington Commission and the corresponding impact on PSE’s revenue based on the effective dates:
	Type of Rate	Effective Date	Average	Increase (Decrease)
	Adjustment		Percentage	in Revenue
			Increase (Decrease)	(Dollars in Millions)
			in Rates
	PCORC	1-Nov-13	-0.50%	($10.50)
	Decoupling Rate Filing	1-Jul-13	1	21.4
	Expedited Rate Filing	1-Jul-13	1.5	30.7
	Electric General Rate Case	May 14, 2012, Annual	3.2	63.3
	Renewable Energy Credit Proceeds	November 1, 2010 - March 31, 2011	-2.9	-27.7
Gas	'
Regulation and Rates [Line Items]	'
Schedule of Effects on Annual Revenue Due to Approved Rate Adjustments	'
	The following table sets forth natural gas rate adjustments that were approved by the Washington Commission and the corresponding impact to PSE’s annual revenue based on the effective dates:
	Type of Rate	Effective Date	Average	Annual
	Adjustment		Percentage	Increase (Decrease)
			Increase (Decrease)	in Revenue
			in Rates	(Dollars in Millions)
	Purchased Gas Adjustment	1-Nov-13	0.40%	$4.00
	Decoupling Rate Filing	1-Jul-13	1.1	10.8
	Expedited Rate Filing	1-Jul-13	-0.2	-2
	Purchased Gas Adjustment	1-Nov-12	-7.7	-77
	Natural Gas General Rate Case	14-May-12	1.3	13.4
	Purchased Gas Adjustment	1-Nov-11	-4.3	-43.5
	Natural Gas General Tariff Adjustment	1-Apr-11	1.8	19

Utility_Plant_Tables

Utility Plant (Tables)	12 Months Ended
	Dec. 31, 2013
Utility Plant [Abstract]	'
Schedule of Utility Plant	'
			Puget Energy						Puget Sound Energy
	Utility Plant	Estimated	At December 31,						At December 31,
		Useful Life
	(Dollars In Thousands)	(Years)	2013			2012			2013			2012
	Electric, gas and common utility plant classified by prescribed accounts :
	Distribution plant	Oct-50	$	4,448,451		$	4,276,123		$	6,127,732		$	5,993,055
	Production plant	25-125	2,966,223			2,480,135			3,948,270			3,464,528
	Transmission plant	45-65	1,043,605			984,018			1,162,929			1,108,104
	General plant	May-35	504,965			445,982			599,156			543,195
	Intangible plant (including capitalized software)	Mar-50	316,614			181,884			309,972			181,596
	Plant acquisition adjustment	30-Jul	242,826			242,659			282,792			282,624
	Underground storage	25-60	27,857			27,331			41,501			40,987
	Liquefied natural gas storage	25-45	12,622			12,622			14,492			14,492
	Plant held for future use	NA	28,742			18,416			28,895			18,568
	Recoverable Cushion Gas	NA	8,655			8,655			8,655			8,655
	Plant not classified	NA	124,589			155,626			124,589			155,625
	Capital leases, net of accumulated amortization 1	5	17,051			24,629			17,051			24,629
	Less: accumulated provision for depreciation		(1,373,178		)	(1,067,424		)	(4,297,012		)	(4,045,402		)
	Subtotal		$	8,369,022		$	7,790,656		$	8,369,022		$	7,790,656
	Construction work in progress	NA	310,318			766,035			310,318			766,035
	Net utility plant		$	8,679,340		$	8,556,691		$	8,679,340		$	8,556,691
	_______________
	1	Accumulated amortization of capital leases at Puget Energy was $20.8 million in 2013 and $13.3 million in 2012.  Accumulated amortization of capital leases at PSE was $20.8 million in 2013 and $13.3 million in 2012.
Schedule of Jointly Owned Utility Plants	'
	These amounts are also included in the Utility Plant table above.
					Puget Energy’s						Puget Sound Energy’s
					Share						Share
	Jointly Owned Generating Plants	Energy Source (Fuel)	Company’s Ownership Share		Plant in Service at Cost			Accumulated Depreciation			Plant in Service at Cost			Accumulated Depreciation
	(Dollars in Thousands)
	Colstrip Units 1 & 2	Coal	50	%	$	162,090		$	(20,875	)	$	297,494		$	(156,278	)
	Colstrip Units 3 & 4	Coal	25	%	234,984			(33,270		)	513,992			(312,278		)
	Colstrip Units 1 – 4 Common Facilities	Coal	various		83			(17		)	252			(185		)
	Frederickson 1	Gas	49.85	%	61,785			(4,255		)	70,719			(13,189		)
Schedule of Asset Retirement Obligations	'
	The following table describes all changes to the Company’s ARO liability:
		At December 31,
	(Dollars in Thousands)	2013			2012
	Asset retirement obligation at beginning of period	$	45,496		$	26,540
	New asset retirement obligation recognized in the period	350			7,737
	Liability settled in the period	(1,188		)	(2,960		)
	Revisions in estimated cash flows	2,769			12,632
	Accretion expense	1,260			1,547
	Asset retirement obligation at end of period	$	48,687		$	45,496

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Instrument [Line Items]	'
Schedule of Long-Term Debt Instruments	'
	(Dollars in Thousands)			At December 31,
	Series	Type	Due	2013			2012
	Puget Sound Energy:
	6.83%	First Mortgage Bond	2013	$	—		$	3,000
	6.90%	First Mortgage Bond	2013	—			10,000
	7.35%	First Mortgage Bond	2015	10,000			10,000
	7.36%	First Mortgage Bond	2015	2,000			2,000
	5.20%	Senior Secured Note	2015	150,000			150,000
	6.75%	Senior Secured Note	2016	250,000			250,000
	5.50%	Promissory Note 1	2017	2,412			2,412
	6.74%	Senior Secured Note	2018	200,000			200,000
	7.15%	First Mortgage Bond	2025	15,000			15,000
	7.20%	First Mortgage Bond	2025	2,000			2,000
	7.02%	Senior Secured Note	2027	300,000			300,000
	7.00%	Senior Secured Note	2029	100,000			100,000
	3.90%	Pollution Control Bond	2031	138,460			—
	4.00%	Pollution Control Bond	2031	23,400			—
	5.00%	Pollution Control Bond	2031	—			138,460
	5.10%	Pollution Control Bond	2031	—			23,400
	5.48%	Senior Secured Note	2035	250,000			250,000
	6.72%	Senior Secured Note	2036	250,000			250,000
	6.27%	Senior Secured Note	2037	300,000			300,000
	5.76%	Senior Secured Note	2039	350,000			350,000
	5.80%	Senior Secured Note	2040	325,000			325,000
	5.76%	Senior Secured Note	2040	250,000			250,000
	4.43%	Senior Secured Note	2041	250,000			250,000
	5.64%	Senior Secured Note	2041	300,000			300,000
	4.70%	Senior Secured Note	2051	45,000			45,000
	6.97%	Junior Subordinated Note	2067	250,000			250,000
		Unamortized discount on senior notes		(14		)	(14		)
	PSE long-term debt			$	3,763,258		$	3,776,258
	Puget Energy:
		Fair value adjustment of PSE long-term debt		$	(229,746	)	$	(264,017	)
		Credit Facility	2017	299,000			434,000
	6.50%	Senior Secured Note	2020	450,000			450,000
	6.00%	Senior Secured Note	2021	500,000			500,000
	5.63%	Senior Secured Note	2022	450,000			450,000
		Unamortized discount on senior notes		(36		)	(41		)
	Total Puget Energy long-term debt			$	5,232,476		$	5,346,200
	_______________
	1	Puget Western, Inc., a wholly owned subsidiary of PSE, Promissory Note.
Schedule of Maturities of Long-Term Debt	'
	The principal amounts of long-term debt maturities for the next five years and thereafter are as follows:
	(Dollars in Thousands)	2014			2015			2016		2017		2018		Thereafter		Total
	Maturities of:
	PSE long-term debt	$	—		$	162,000		$	250,000	$	2,412	$	200,000	$	3,148,860	$	3,763,272
	Puget Energy long-term debt	—			—			—		299,000		—		1,400,000		1,699,000
	Puget Energy long-term debt	$	—		$	162,000		$	250,000	$	301,412	$	200,000	$	4,548,860	$	5,462,272

Leases_Tables

Leases (Tables)	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
Schedule of Operating Lease Expense	'
	Operating lease expenses net of sublease receipts were:
	(Dollars in Thousands)
	At December 31,
	2013	$	29,392
	2012	29,661
	2011	24,789
Schedule of Future Minimum Lease Payments for Non-cancellable Leases	'
	Future minimum lease payments for non-cancelable leases net of sublease receipts are:
	(Dollars in Thousands)
	At December 31,	Operating		Capital
	2014	$	16,603	$	8,160
	2015	16,963		8,160
	2016	18,922		2,718
	2017	18,852		—
	2018	16,051		—
	Thereafter	68,847		—
	Total minimum lease payments	$	156,238	$	19,038

Accounting_for_Derivative_Inst1

Accounting for Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative [Line Items]	'
Schedule of Credit Risk Related Contingent Features [Table Text Block]	'
	The table below presents the fair value of the overall contractual contingent liability positions for the Company's derivative activity at December 31, 2013:
	Puget Energy and Puget Sound Energy	Fair Value 1			Posted			Contingent
	Contingent Feature	Liability			Collateral			Collateral
	(Dollars in Thousands)
	Credit rating 2	$	(12,561	)	$	—		$	12,561
	Requested credit for adequate assurance	(22,415		)	—			—
	Forward value of contract 3	(49		)	—			—
	Total	$	(35,025	)	$	—		$	12,561
	__________
	1	Represents the derivative fair value of contracts with contingent features for counterparties in net derivative liability positions. Excludes NPNS, accounts payable and accounts receivable.
	2	Failure by PSE to maintain an investment grade credit rating from each of the major credit rating agencies provides counterparties a contractual right to demand collateral.
	3	Collateral requirements may vary, based on changes in the forward value of underlying transactions relative to contractually defined collateral thresholds.
Offsetting Assets and Liabilities [Table Text Block]	'
	The following tables present the potential effect of netting arrangements, including rights of set-off associated with the Company's derivative assets and liabilities:
	Puget Energy and Puget Sound Energy
	At December 31, 2013
	(Dollars in Thousands)	Gross Amounts Recognized in the Statement of Financial Position 1			Gross Amounts Offset in the Statement of Financial Position			Net of Amounts Presented in the Statement of Financial Position			Gross Amounts Not Offset in the Statement of Financial Position
											Commodity Contracts			Cash Collateral Received/Posted			Net Amount
	Assets
	Energy Derivative Contracts	$	26,600		$	—		$	26,600		$	(19,491	)	$	—		$	7,109
	Liabilities
	Energy Derivative Contracts	$	72,988		$	—		$	72,988		$	(19,491	)	$	—		$	53,497
	Interest Rate Swaps 2	$	13,223		$	—		$	13,223		$	—		$	—		$	13,223
	Puget Energy and Puget Sound Energy
	At December 31, 2012
	(Dollars in Thousands)	Gross Amounts Recognized in the Statement of Financial Position 1			Gross Amounts Offset in the Statement of Financial Position			Net of Amounts Presented in the Statement of Financial Position			Gross Amounts Not Offset in the Statement of Financial Position
											Commodity Contracts			Cash Collateral Received/Posted			Net Amount
	Assets
	Energy Derivative Contracts	$	21,683		$	—		$	21,683		$	(14,126	)	$	—		$	7,557
	Liabilities
	Energy Derivative Contracts	$	239,271		$	—		$	239,271		$	(14,126	)	$	—		$	225,145
	Interest Rate Swaps 2	$	21,524		$	—		$	21,524		$	—		$	—		$	21,524
	___________
	1.	All Derivative Contract deals are executed under ISDA, NAESB and WSPP Master Netting Agreements with Right of Offset.
	2	Interest Rate Swap Contracts are only held at Puget Energy.
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	'
	The following table presents the volumes, fair values and locations of the Company's derivative instruments recorded on the balance sheets:
	Puget Energy and	Year Ended December 31,
	Puget Sound Energy
	(Dollars in Thousands)	Volumes (millions)				Assets 1						Liabilities 2
		2013		2012		2013			2012			2013			2012
	Interest rate swap derivatives 3	$450.00		$450.00		$	—		$	—		$	13,223		$	21,524
	Electric portfolio derivatives	*		*		18,479			9,557			37,312			131,193
	Natural gas derivatives (MMBtus) 4	423.5		516.9		8,121			12,126			35,676			108,078
	Total derivative contracts					$	26,600		$	21,683		$	86,211		$	260,795
	Current					$	18,867		$	6,869		$	48,049		$	177,519
	Long-term					7,733			14,814			38,162			83,276
	Total derivative contracts					$	26,600		$	21,683		$	86,211		$	260,795
	___________
	1	Balance sheet location: Current and Long-term Unrealized gain on derivative instruments.
	2	Balance sheet location: Current and Long-term Unrealized loss on derivative instruments.
	3	Interest rate swap contracts are only held at Puget Energy.
	4	PSE had a net derivative liability and an offsetting regulatory asset of $27.6 million at December 31, 2013 and $96.0 million at December 31, 2012 related to contracts used to economically hedge the cost of physical gas purchased to serve natural gas customers. All fair value adjustments on derivatives relating to the natural gas business have been deferred in accordance with ASC 980, due to the PGA mechanism.
	*	Electric portfolio derivatives consist of electric generation fuel of 145.6 million One Million British Thermal Units (MMBtus) and purchased electricity of 8.6 million MWhs at December 31, 2013 and 129.7 million MMBtus and 10.7 million MWhs at December 31, 2012.
Parent Company [Member]	'
Derivative [Line Items]	'
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block]	'
	The following tables present the effect and locations of the Company's derivatives not designated as hedging instruments, recorded on the statements of income:
	Puget Energy		Year Ended December 31,
	(Dollars in Thousands)	Location	2013			2012			2011
	Interest rate contracts:	Other deductions	$	2,420		$	(4,288	)	$	(28,601	)
		Interest expense	(5,904		)	(29,727		)	(46,045		)
	Commodity contracts:
	Electric derivatives	Unrealized gain (loss) on derivative instruments, net 1	102,744			131,407			(23,171		)
		Electric generation fuel	(27,008		)	(66,762		)	(98,208		)
		Purchased electricity	(38,299		)	(138,551		)	(66,845		)
	Total gain (loss) recognized in income on derivatives		$	33,953		$	(107,921	)	$	(262,870	)
	___________
	1	For 2012 and 2011, the amounts differ from the amounts stated in the statements of income as they do not include amortization related to contracts that were recorded at fair value at the time of the February 2009 merger and subsequently designated as NPNS of $2.2 million for the year ended December 31, 2012 and $11.7 million for the year ended December 31, 2011.
PUGET SOUND ENERGY, INC.	'
Derivative [Line Items]	'
Schedule of Derivative Instruments, Effect on Other Comprehensive Income (Loss) [Table Text Block]	'
	Puget Sound Energy		Year Ended December 31,
	(Dollars in Thousands)	Location	2013			2012			2011
	Interest rate contracts:	Interest expense	$	(488	)	$	(488	)	$	(488	)
	Commodity contracts:
	Electric derivatives	Electric generation fuel	—			97			(20,625		)
		Purchased electricity	(3,922		)	(12,955		)	(12,726		)
	Total		$	(4,410	)	$	(13,346	)	$	(33,839	)
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block]	'
	Puget Sound Energy		Year Ended December 31,
	(Dollars in Thousands)	Location	2013			2012			2011
	Commodity contracts:
	Electric derivatives	Unrealized gain (loss) on derivative instruments, net	$	98,880		$	119,120		$	(54,146	)
		Electric generation fuel	(27,008		)	(66,762		)	(98,208		)
		Purchased electricity	(38,299		)	(138,551		)	(66,845		)
	Total gain (loss) recognized in income on derivatives		$	33,573		$	(86,193	)	$	(219,199	)
PUGET ENERGY	'
Derivative [Line Items]	'
Schedule of Derivative Instruments, Effect on Other Comprehensive Income (Loss) [Table Text Block]	'
	The following tables present the Company's pre-tax gain (loss) on derivatives that were previously in a cash flow hedge relationship, and subsequently reclassified out of accumulated OCI into income:
	Puget Energy		Year Ended December 31,
	(Dollars in Thousands)	Location	2013			2012			2011
	Interest rate contracts:	Interest expense	$	(4,505	)	$	(17,811	)	$	(39,143	)
	Commodity contracts:
	Electric derivatives	Electric generation fuel	—			100			(679		)
		Purchased electricity	(57		)	(671		)	(1,698		)
	Total		$	(4,562	)	$	(18,382	)	$	(41,520	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
	The following table presents the carrying value for cash, cash equivalents, restricted cash, notes receivable and short-term debt by level, within the fair value hierarchy. The carrying values below are representative of fair values due to the short-term nature of these financial instruments.
	Puget Energy	Carrying / Fair Value									Carrying / Fair Value
		At December 31, 2013									At December 31, 2012
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	44,302		$	—		$	44,302		$	135,542		$	—		$	135,542
	Restricted Cash	7,171			—			7,171			3,700			—			3,700
	Notes Receivable and Other	—			53,449			53,449			—			63,802			63,802
	Total assets	$	51,473		$	53,449		$	104,922		$	139,242		$	63,802		$	203,044
	Liabilities:
	Short-term debt	$	162,000		$	—		$	162,000		$	181,000		$	—		$	181,000
	Total liabilities	$	162,000		$	—		$	162,000		$	181,000		$	—		$	181,000
Fair Value Inputs, Liabilities, Quantitative Information	'
	The fair value of the junior subordinated and long-term notes were estimated using the discounted cash flow method with U.S. Treasury yields and Company credit spreads as inputs, interpolating to the maturity date of each issue. Carrying values and estimated fair values were as follows:
	Puget Energy		December 31, 2013						December 31, 2012
	(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value
	Liabilities:
	Junior subordinated notes	2	$	250,000		$	269,366		$	250,000		$	264,842
	Long-term debt (fixed-rate), net of discount	2	4,683,476			5,594,314			4,662,200			6,197,179
	Long-term debt (variable-rate)	2	299,000			299,000			434,000			434,000
	Total		$	5,232,476		$	6,162,680		$	5,346,200		$	6,896,021
	Puget Sound Energy		December 31, 2013						December 31, 2012
	(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value
	Liabilities:
	Junior subordinated notes	2	$	250,000		$	269,366		$	250,000		$	264,842
	Long-term debt (fixed-rate), net of discount	2	3,513,258			4,038,455			3,526,258			4,628,509
	Total		$	3,763,258		$	4,307,821		$	3,776,258		$	4,893,351
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]	'
	Puget Energy and	Year Ended December 31,
	Puget Sound Energy
	Level 3 Roll-Forward Net (Liability)	2013									2012									2011
	(Dollars in Thousands)	Electric			Gas			Total			Electric			Gas			Total			Electric			Gas			Total
	Balance at beginning of period	$	(33,924	)	$	(1,602	)	$	(35,526	)	$	(90,311	)	$	(5,041	)	$	(95,352	)	$	(87,436	)	$	(3,859	)	$	(91,295	)
	Changes during period
	Realized and unrealized energy derivatives:
	Included in earnings 1	(10,491		)	—			(10,491		)	(21,362		)	—			(21,362		)	(56,499		)	—			(56,499		)
	Included in regulatory assets / liabilities	—			(945		)	(945		)	—			(1,937		)	(1,937		)	—			(250		)	(250		)
	Settlements 2	11,609			(754		)	10,855			59,133			969			60,102			40,900			(3,418		)	37,482
	Transferred into Level 3	(7,799		)	—			(7,799		)	(55,548		)	(297		)	(55,845		)	(759		)	453			(306		)
	Transferred out of Level 3	25,184			2,940			28,124			74,164			4,704			78,868			13,483			2,033			15,516
	Balance at end of period	$	(15,421	)	$	(361	)	$	(15,782	)	$	(33,924	)	$	(1,602	)	$	(35,526	)	$	(90,311	)	$	(5,041	)	$	(95,352	)
	_______________
	1	Income Statement location: Unrealized (gain) loss on derivative instruments, net. Includes unrealized gains (losses) on derivatives still held in position as of the reporting date for electric derivatives of $(13.4) million, $(15.2) million, and $(55.2) million for the years ended December 31, 2013, 2012 and 2011, respectively.
	2	The Company had no purchases, sales or issuances during the reported periods.
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Table Text Block]	'
	Below are significant unobservable inputs used in estimating the long-term power purchase contracts' fair value of $484.1 million on June 30, 2013:
	Valuation Technique	Unobservable Input	Low	High	Weighted Average
	Discounted cash flow	Power prices	$30.85 per MWh	$65.35 per MWh	$48.47 per MWh
	Discounted cash flow	Power contract costs (in thousands)	$389 per yr	$6,845 per yr	$4,110 per yr
	Below are the forward price ranges for the Company's purchased commodity contracts, as of December 31, 2013:
	(Dollars in Thousands)
		Fair Value				Range
	Derivative Instrument	Assets 1	Liabilities 1	Valuation Technique	Unobservable Input	Low	High	Weighted Average
	Electric	$3,818	$19,239	Discounted cash flow	Power Prices	$17.06 per MWh	$47.09 per MWh	$38.74 per MWh
	Natural gas	$2,673	$3,034	Discounted cash flow	Natural Gas Prices	$3.62 per MMBtu	$4.19 per MMBtu	$3.78 per MMBtu
	_______________
	1	The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions.
	Below are significant unobservable inputs used in estimating the long-term power purchase contracts' fair value on March 31, 2012 and December 31, 2012:
	Valuation Technique	Unobservable Input	Low	High	Weighted Average
	March 31, 2012
	Discounted cash flow	Power prices	$10.36 per MWh	$49.78 per MWh	$34.98 per MWh
	Discounted cash flow	Power contract costs (in thousands)	$3,185 per qtr	$5,030 per qtr	$4,663 per qtr
	December 31, 2012
	Discounted cash flow	Power prices	$16.94 per MWh	$70.89 per MWh	$49.40 per MWh
	Discounted cash flow	Power contract costs (in thousands)	$1,777 per qtr	$7,133 per qtr	$6,603 per qtr
Fair Value, Measurements, Recurring	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
	The following tables present the Company's financial assets and liabilities by level, within the fair value hierarchy, that were accounted for at fair value on a recurring basis and the reconciliation of the changes in the fair value of Level 3 derivatives in the fair value hierarchy:
	Puget Energy	Fair Value									Fair Value
		At December 31, 2013									At December 31, 2012
	(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
	Interest rate derivative instruments	$	13,223		$	—		$	13,223		$	21,524		$	—		$	21,524
	Total derivative liabilities	$	13,223		$	—		$	13,223		$	21,524		$	—		$	21,524
	Puget Energy and	Fair Value									Fair Value
	Puget Sound Energy	At December 31, 2013									At December 31, 2012
	(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
	Assets:
	Electric derivative instruments	$	14,661		$	3,818		$	18,479		$	1,259		$	8,298		$	9,557
	Natural gas derivative instruments	5,448			2,673			8,121			6,769			5,357			12,126
	Total assets	$	20,109		$	6,491		$	26,600		$	8,028		$	13,655		$	21,683
	Liabilities:
	Electric derivative instruments	$	18,073		$	19,239		$	37,312		$	88,971		$	42,221		$	131,192
	Natural gas derivative instruments	32,642			3,034			35,676			101,119			6,960			108,079
	Total liabilities	$	50,715		$	22,273		$	72,988		$	190,090		$	49,181		$	239,271
PUGET SOUND ENERGY, INC.	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
	Puget Sound Energy	Carrying / Fair Value									Carrying / Fair Value
		At December 31, 2013									At December 31, 2012
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	44,111		$	—		$	44,111		$	135,530		$	—		$	135,530
	Restricted Cash	7,171			—			7,171			3,700			—			3,700
	Notes Receivable and Other	—			53,449			53,449			—			63,802			63,802
	Total assets	$	51,282		$	53,449		$	104,731		$	139,230		$	63,802		$	203,032
	Liabilities:
	Short-term debt	$	162,000		$	—		$	162,000		$	181,000		$	—		$	181,000
	Short-term debt owed to parent	—			29,598			29,598			—			29,598			29,598
	Total liabilities	$	162,000		$	29,598		$	191,598		$	181,000		$	29,598		$	210,598

Retirement_Benefits_Tables

Retirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2013
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Schedule of Changes in Projected Benefit Obligations	'
	The following tables summarize the Company’s change in benefit obligation, change in plan assets and amounts recognized in the Statements of Financial Position for the years ended December 31, 2013 and 2012:
	Puget Energy and	Qualified						SERP						Other
	Puget Sound Energy	Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Change in benefit obligation:
	Benefit obligation at beginning of period	$	616,290		$	565,997		$	51,795		$	48,370		$	17,672		$	16,436
	Service cost	19,285			16,926			1,498			1,073			134			139
	Interest cost	24,754			25,986			2,045			2,152			664			751
	Amendment	—			—			478			(122		)	—			—
	Actuarial loss/(gain)	(48,559		)	40,914			(1,687		)	5,483			(2,240		)	1,199
	Benefits paid	(38,453		)	(33,533		)	(6,850		)	(5,161		)	(1,536		)	(1,523		)
	Medicare part D subsidy received	—			—			—			—			245			670
	Benefit obligation at end of period	$	573,317		$	616,290		$	47,279		$	51,795		$	14,939		$	17,672
Schedule of Changes in Fair Value of Plan Assets	'
	Puget Energy and	Qualified						SERP						Other
	Puget Sound Energy	Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Change in plan assets:
	Fair value of plan assets at beginning of period	$	531,183		$	479,786		$	—		$	—		$	7,541		$	7,206
	Actual return on plan assets	102,591			62,130			—			—			1,861			1,100
	Employer contribution	20,400			22,800			6,850			5,161			908			758
	Benefits paid	(38,453		)	(33,533		)	(6,850		)	(5,161		)	(1,536		)	(1,523		)
	Fair value of plan assets at end of period	$	615,721		$	531,183		$	—		$	—		$	8,774		$	7,541
	Funded status at end of period	$	42,404		$	(85,107	)	$	(47,279	)	$	(51,795	)	$	(6,165	)	$	(10,131	)
Schedule of Amounts Recognized in Balance Sheet and Accumulated Other Comprehensive Income	'
	Puget Energy and	Qualified						SERP						Other
	Puget Sound Energy	Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Amounts recognized in Statement of Financial Position consist of:
	Noncurrent assets	$	42,404		$	—		$	—		$	—		$	—		$	—
	Current liabilities	—			—			(3,981		)	(5,040		)	(421		)	(460		)
	Noncurrent liabilities	—			(85,107		)	(43,298		)	(46,755		)	(5,744		)	(9,671		)
	Net assets / (liabilities)	$	42,404		$	(85,107	)	$	(47,279	)	$	(51,795	)	$	(6,165	)	$	(10,131	)
Schedule of Net Benefit Costs	'
	Puget Energy	Qualified									SERP									Other
		Pension Benefits									Pension Benefits									Benefits
	(Dollars in Thousands)	2013			2012			2011			2013			2012			2011			2013			2012			2011
	Components of net periodic benefit cost:
	Service cost	$	19,285		$	16,926		$	15,822		$	1,498		$	1,073		$	1,241		$	134		$	139		$	113
	Interest cost	24,754			25,986			26,263			2,045			2,152			2,192			664			751			806
	Expected return on plan assets	(39,095		)	(36,203		)	(35,344		)	—			—			—			(436		)	(435		)	(502		)
	Amortization of prior service cost/(credit)	(1,980		)	(1,980		)	(1,980		)	(17		)	—			—			—			—			—
	Amortization of net loss	2,889			768			—			1,461			702			360			69			53			(46		)
	Net periodic benefit cost	$	5,853		$	5,497		$	4,761		$	4,987		$	3,927		$	3,793		$	431		$	508		$	371
Schedule of Amounts Recognized in Other Comprehensive Income (Loss)	'
	Puget Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Other changes (pre-tax) in plan assets and benefit obligations recognized in other comprehensive income:
	Net loss/(gain)	$	(112,055	)	$	14,988		$	(1,687	)	$	5,483		$	(3,665	)	$	534
	Amortization of net loss/(gain)	(2,889		)	(768		)	(1,461		)	(703		)	(70		)	(53		)
	Prior service credit	—			—			478			(122		)	—			—
	Amortization of prior service credit	1,980			1,980			17			—			—			—
	Total change in other comprehensive income for year	$	(112,964	)	$	16,200		$	(2,653	)	$	4,658		$	(3,735	)	$	481
Schedule of Assumptions Used	'
	In accounting for pension and other benefit obligations and costs under the plans, the following weighted-average actuarial assumptions were used by the Company:
		Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
	Benefit Obligation Assumptions	2013		2012		2011		2013		2012		2011		2013		2012		2011
	Discount rate 1	5.1	%	4.15	%	4.75	%	5.1	%	4.15	%	4.75	%	5.1	%	4.15	%	4.75	%
	Rate of compensation increase	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%
	Medical trend rate	—		—		—		—		—		—		6.8	%	7.5	%	7.5	%
	Benefit Cost Assumptions
	Discount rate	4.15	%	4.75	%	5.15	%	4.15	%	4.75	%	5.15	%	4.15	%	4.75	%	5.15	%
	Rate of plan assets	7.75	%	7.75	%	7.75	%	—		—		—		6.9	%	7.5	%	7.8	%
	Rate of compensation increase	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%	4.5	%
	Medical trend rate	—		—		—		—		—		—		8.2	%	7.5	%	8	%
	_______________
	1	The Company calculates the present value of the pension liability using a discount rate of 5.10% which represents the single-rate equivalent of the AA rated corporate bond yield curve.
Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates	'
	A 1.0% change in the assumed medical inflation rate would have the following effects:
		2013						2012
	(Dollars in Thousands)	1% Increase			1% Decrease			1% Increase			1% Decrease
	Effect on post-retirement benefit obligation	$	66		$	(66	)	$	92		$	(92	)
	Effect on service and interest cost components	3			(3		)	4			(4		)
Schedule of Expected Benefit Payments	'
	The expected total benefits to be paid under the next five years and the aggregate total to be paid for the five years thereafter are as follows:
	(Dollars in Thousands)	2014			2015			2016			2017			2018			2019-2023
	Qualified Pension total benefits	$	40,000		$	40,200		$	40,200		$	41,100		$	42,300		$	226,900
	SERP Pension total benefits	3,981			1,985			2,541			1,900			5,177			18,392
	Other Benefits total with Medicare Part D subsidy	1,222			1,193			1,242			1,197			1,149			6,276
	Other Benefits total without Medicare Part D subsidy	1,604			1,591			1,555			1,519			1,479			6,709
Schedule of Allocation of Plan Assets	'
	To obtain the desired return needed to fund the pension benefit plans, the Retirement Plan Committee has established investment allocation percentages by asset classes as follows:
		Allocation
	Asset Class	Minimum	Target	Maximum
	Domestic large cap equity	25%	31%	40%
	Domestic small cap equity	0%	9%	15%
	Non-U.S. equity	10%	25%	30%
	Fixed income	15%	25%	30%
	Real estate	0%	0%	10%
	Absolute return	5%	10%	15%
	Cash	0%	0%	5%
	The following table sets forth by level, within the fair value hierarchy, the qualified pension plan as of December 31, 2013 and 2012:
		Recurring Fair Value Measures												Recurring Fair Value Measures
		As of December 31, 2013												As of December 31, 2012
	(Dollars in Thousands)	Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
	Assets:
	Equities:
	Non-US equity 1	$	76,188		$	78,816		$	—		$	155,004		$	56,717		$	49,304		$	—		$	106,021
	Domestic large cap equity 2	157,874			35,851			—			193,725			136,994			28,890			—			165,884
	Domestic small cap equity 3	62,867			—			—			62,867			51,264			—			—			51,264
	Total equities	296,929			114,667			—			411,596			244,975			78,194			—			323,169
	Tactical asset allocation 4	—			—			—			—			—			26,425			—			26,425
	Fixed income securities 5	135,007			—			—			135,007			119,939			—			—			119,939
	Absolute return 6	—			—			62,278			62,278			—			—			55,615			55,615
	Cash and cash equivalents 7	—			7,054			—			7,054			—			6,019			—			6,019
	Subtotal	$	431,936		$	121,721		$	62,278		$	615,935		$	364,914		$	110,638		$	55,615		$	531,167
	Net (payable) receivable										(417		)										(173		)
	Accrued income										203												189
	Total assets										$	615,721											$	531,183
	_________________
	1	Non – US Equity investments are comprised of a (1) mutual fund; and a (2) commingled fund.  The investment in the mutual fund is valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013.  The investment in the commingled fund is valued at the net asset value per share multiplied by the number of shares held as of December 31, 2013.
	2	Domestic large cap equity investments are comprised of (1) common stock, and a (2) commingled fund.  Investments in common stock are valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013.  The investment in the commingled fund is valued at the net asset value per share multiplied by the number of shares held as of December 31, 2013.
	3	Domestic small cap equity investments are comprised of (1) common stock and a (2) mutual fund. The investments in common stock are valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013. The investment in the mutual fund is valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013.
	4	The tactical asset allocation investment is comprised of a commingled fund, which is valued at the net asset value per share multiplied by the number of shares held as of the measurement date.
	5	Fixed income securities consist of a mutual fund.  The investment in the mutual fund is valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013.
	6	As of December 31, 2013 absolute return investments consist of two partnerships.  The partnerships are valued using the financial reports as of December 31, 2013.  These investments are a Level 3 under ASC 820 because the significant valuation inputs are primarily internal to the partnerships with little third party involvement.
	7	The investment consists of a money market fund, which is valued at the net asset value per share of $1.00 per unit as of December 31, 2013.  The money market fund invests primarily in commercial paper, notes, repurchase agreements, and other evidences of indebtedness which are payable on demand or short-term in nature.
	The following table sets forth by level, within the fair value hierarchy, the Other Benefits plan assets which consist of insurance benefits for retired employees, at fair value:
		Recurring Fair Value Measures									Recurring Fair Value Measures
		As of December 31, 2013									As of December 31, 2012
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Mutual fund 1	$	8,703		$	—		$	8,703		$	7,472		$	—		$	7,472
	Cash equivalents 2	—			71			71			—			69			69
	Total assets	$	8,703		$	71		$	8,774		$	7,472		$	69		$	7,541
	_______________
	1	This is a publicly traded balanced mutual fund.  The fund seeks regular income, conservation of principal, and an opportunity for long-term growth of principal and income.  The fair value is determined by taking the number of shares owned by the plan, and multiplying by the market price as of December 31, 2013.
	2	This is a money market fund.  The money market fund investments are valued at the net asset value per share of $1.00 per unit as of December 31, 2013.  The money market fund invests primarily in commercial paper, notes, repurchase agreements, and other evidences of indebtedness which are payable on demand or short-term in nature.
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets	'
	Level 3 Roll-Forward
	The following table sets forth a reconciliation of changes in the fair value of the plan’s Level 3 assets:
		As of December 31, 2013									As of December 31, 2012
	(Dollars in Thousands)	Partnership			Mutual Funds			Total			Partnership			Mutual Funds			Total
	Balance at beginning of year	$	55,614		$	—		$	55,614		$	45,319		$	—		$	45,319
	Additional investments	—			—			—			7,021			—			7,021
	Distributions	—			—			—			—			—			—
	Realized losses on distributions	—			—			—			—			—			—
	Unrealized gains relating to instruments still held at the reporting date	6,664			—			6,664			3,274			—			3,274
	Transferred out of level 3 1	—			—			—			—			—			—
	Balance at end of year	$	62,278		$	—		$	62,278		$	55,614		$	—		$	55,614
	_________________
	1	The plan had no transfers between level 2 and level 1 during the years ended December 31, 2013 or 2012.
PUGET ENERGY	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Schedule of Amounts Recognized in Balance Sheet and Accumulated Other Comprehensive Income	'
	Puget Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Amounts recognized in Accumulated Other Comprehensive Income consist of:
	Net loss/(gain)	$	(65,943	)	$	49,001		$	9,670		$	12,818		$	(2,972	)	$	763
	Prior service cost / (credit)	(15,762		)	(17,741		)	373			(122		)	—			—
	Total	$	(81,705	)	$	31,260		$	10,043		$	12,696		$	(2,972	)	$	763
PUGET SOUND ENERGY, INC.	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Schedule of Amounts Recognized in Balance Sheet and Accumulated Other Comprehensive Income	'
	Puget Sound Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Amounts recognized in Accumulated Other Comprehensive Income consist of:
	Net loss/(gain)	$	138,324		$	269,401		$	14,050		$	17,928		$	(5,556	)	$	(2,175	)
	Prior service cost/(credit)	(12,525		)	(14,098		)	383			(110		)	6			36
	Total	$	125,799		$	255,303		$	14,433		$	17,818		$	(5,550	)	$	(2,139	)
Schedule of Net Benefit Costs	'
	Puget Sound Energy	Qualified									SERP									Other
		Pension Benefits									Pension Benefits									Benefits
	(Dollars in Thousands)	2013			2012			2011			2013			2012			2011			2013			2012			2011
	Components of net periodic benefit cost:
	Service cost	$	19,285		$	16,926		$	15,822		$	1,498		$	1,073		$	1,241		$	134		$	139		$	113
	Interest cost	24,753			25,986			26,263			2,045			2,152			2,192			664			751			806
	Expected return on plan assets	(40,685		)	(41,533		)	(44,128		)	—			—			—			(436		)	(435		)	(502		)
	Amortization of prior service cost/(credit)	(1,573		)	(1,573		)	(1,573		)	(16		)	293			563			30			35			63
	Amortization of net loss/(gain)	20,612			15,015			10,250			2,191			1,432			1,194			(284		)	(245		)	(481		)
	Amortization of transition obligation	—			—			—			—			—			—			—			50			50
	Net periodic benefit cost	$	22,392		$	14,821		$	6,634		$	5,718		$	4,950		$	5,190		$	108		$	295		$	49
Schedule of Amounts Recognized in Other Comprehensive Income (Loss)	'
	Puget Sound Energy	Qualified						SERP						Other
		Pension Benefit						Pension Benefits						Benefits
	(Dollars in Thousands)	2013			2012			2013			2012			2013			2012
	Other changes (pre-tax) in plan assets and benefit obligations recognized in other comprehensive income:
	Net loss/(gain)	$	(110,465	)	$	20,318		$	(1,687	)	$	5,483		$	(3,665	)	$	534
	Amortization of net (loss)/gain	(20,612		)	(15,015		)	(2,191		)	(1,433		)	284			245
	Prior service cost/(credit)	—			—			477			(122		)	—			—
	Amortization of prior service cost/(credit)	1,573			1,573			16			(293		)	(30		)	(35		)
	Amortization of transition obligation	—			—			—			—			—			(50		)
	Total change in other comprehensive income for year	$	(129,504	)	$	6,876		$	(3,385	)	$	3,635		$	(3,411	)	$	694

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosures [Line Items]	'
Schedule of Components of Income Tax Expense (Benefit)	'
	The details of income tax (benefit) expense are as follows:
	Puget Energy	Year Ended December 31,
	(Dollars in Thousands)	2013			2012			2011
	Charged to operating expenses:
	Current:
	Federal	$	—		$	4,268		$	785
	State	—			—			(50		)
	Deferred:
	Federal	122,559			100,701			32,706
	State	(151		)	(244		)	319
	Total income tax expense	$	122,408		$	104,725		$	33,760
Schedule of Effective Income Tax Rate Reconciliation	'
	Puget Energy	Year Ended December 31,
	(Dollars in Thousands)	2013			2012			2011
	Income taxes at the statutory rate	$	142,847		$	132,491		$	54,968
	Increase (decrease):
	Production tax credit	(22,414		)	(22,188		)	(23,310		)
	AFUDC excluded from taxable income	(9,406		)	(16,543		)	(22,861		)
	Capitalized interest	7,294			9,757			17,592
	Utility plant differences	9,527			8,674			5,849
	Treasury grant amortization	(7,651		)	(1,007		)	—
	Tenaska gas contract	1			(4,687		)	7,094
	Other - net	2,210			(1,772		)	(5,572		)
	Total income tax expense	$	122,408		$	104,725		$	33,760
	Effective tax rate	30		%	27.7		%	21.5		%
Schedule of Deferred Tax Assets and Liabilities	'
	The Company’s deferred tax liability at December 31, 2013 and 2012 is composed of amounts related to the following types of temporary differences:
	Puget Energy	At December 31,
	(Dollars in Thousands)	2013			2012
	Utility plant and equipment	$	1,625,107		$	1,409,216
	Regulatory asset for income taxes	146,867			119,844
	Fair value of debt instruments	76,991			86,831
	Other deferred tax liabilities	202,189			151,820
	Subtotal deferred tax liabilities	2,051,154			1,767,711
	Net operating loss carryforward	(374,606		)	(298,440		)
	Production tax credit carryforward	(135,531		)	(113,117		)
	Regulatory liability on production tax credit	(71,880		)	(59,811		)
	Fair value of derivative instruments	(7,166		)	(44,835		)
	Other deferred tax assets	(60,970		)	(43,309		)
	Subtotal deferred tax assets	(650,153		)	(559,512		)
	Total	$	1,401,001		$	1,208,199
Schedule of Deferred Income Taxes by Balance Sheet Location	'
	The above amounts have been classified in the Consolidated Balance Sheets as follows:
	Puget Energy	At December 31
	(Dollars in Thousands)	2013			2012
	Current deferred taxes	$	(86,004	)	$	(53,437	)
	Non-current deferred taxes	1,487,005			1,261,636
	Total	$	1,401,001		$	1,208,199
PUGET SOUND ENERGY, INC.	'
Income Tax Disclosures [Line Items]	'
Schedule of Components of Income Tax Expense (Benefit)	'
	Puget Sound Energy	Year Ended December 31,
	(Dollars in Thousands)	2013			2012			2011
	Charged to operating expenses:
	Current:
	Federal	$	—		$	4,268		$	653
	State	—			—			—
	Deferred:
	Federal	160,886			145,040			76,369
	State	—			—			1,095
	Total income tax expense	$	160,886		$	149,308		$	78,117
Schedule of Effective Income Tax Rate Reconciliation	'
	Puget Sound Energy	Year Ended December 31,
	(Dollars in Thousands)	2013			2012			2011
	Income taxes at the statutory rate	$	180,955		$	176,917		$	98,783
	Increase (decrease):
	Production tax credit	(22,414		)	(22,188		)	(23,310		)
	AFUDC excluded from taxable income	(9,406		)	(16,543		)	(22,861		)
	Capitalized interest	7,294			9,757			17,592
	Utility plant differences	9,527			8,674			5,849
	Treasury grant amortization	(7,651		)	(1,007		)	—
	Tenaska gas contract	1			(4,687		)	7,094
	Other - net	2,580			(1,615		)	(5,030		)
	Total income tax expense	$	160,886		$	149,308		$	78,117
	Effective tax rate	31.1		%	29.5		%	27.7		%
Schedule of Deferred Tax Assets and Liabilities	'
	Puget Sound Energy	At December 31,
	(Dollars In Thousands)	2013			2012
	Utility plant and equipment	$	1,625,107		$	1,409,216
	Regulatory asset for income taxes	146,350			119,279
	Other deferred tax liabilities	131,977			132,304
	Subtotal deferred tax liabilities	1,903,434			1,660,799
	Net operating loss carryforward	(173,068		)	(134,513		)
	Production tax credit carryforward	(135,531		)	(113,117		)
	Regulatory liability on production tax credit	(71,880		)	(59,811		)
	Fair value of derivative instruments	(9,988		)	(46,139		)
	Other deferred tax assets	(69,175		)	(100,632		)
	Subtotal deferred tax assets	(459,642		)	(454,212		)
	Total	$	1,443,792		$	1,206,587
Schedule of Deferred Income Taxes by Balance Sheet Location	'
	Puget Sound Energy	At December 31
	(Dollars in Thousands)	2013			2012
	Current deferred taxes	$	(141,058	)	$	(68,015	)
	Non-current deferred taxes	1,584,850			1,274,602
	Total	$	1,443,792		$	1,206,587

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Long-term Contracts for Purchase of Electric Power	'
	The Company's expenses under these PUD contracts were as follows for the years ended December 31:
	(Dollars in Thousands)				2013			2012			2011
	PUD contract costs				$	63,365		$	70,188		$	81,828
	As of December 31, 2013, the Company purchased portions of the power output of the PUDs' projects as set forth in the following table:
			Company's Current Share of
	(Dollars in Thousands)	Contract	Percent of		Megawatt Capacity		Estimated 2014 Costs			2014 Debt Service Costs			Interest included in 2014 Debt Service Costs			Debt Outstanding
		Expiration	Output
	Chelan County PUD:
	Rock Island Project	2031	25	%	156		$	29,182		$	11,288		$	6,412		$	102,522
	Rocky Reach Project	2031	25	%	325		26,484			8,787			3,563			58,055
	Douglas County PUD:
	Wells Project	2018	29.9	%	251		16,258			8,675			2,678			71,679
	Grant County PUD:
	Priest Rapids Development	2052	0.8	%	9		4,032			2,175			1,274			23,738
	Wanapum Development	2052	0.8	%	9		4,032			2,175			1,274			23,738
	Total				750		$	79,988		$	33,100		$	15,201		$	279,732
Schedule of Long-term Purchase Commitments	'
	The following table summarizes the Company’s estimated obligations for service contracts through the terms of its existing contracts.
	Service Contract Obligations	2014			2015			2016			2017			2018			Thereafter		Total
	(Dollars in Thousands)
	Energy production service contracts 1	$	26,714		$	33,068		$	15,728		$	5,658		$	4,165		$	27,182	$	112,515
	Automated meter reading system 2	23,443			24,176			13,063			9,558			9,994			80,106		160,340
	Total	$	50,157		$	57,244		$	28,791		$	15,216		$	14,159		$	107,288	$	272,855
	_______________
	1	Energy production service contracts include operations and maintenance contracts on Mint Farm, Wild Horse, Goldendale, Hopkins Ridge, Frederickson 1, Ferndale and Lower Snake River facilities.
	2	Automated meter reading system contractual obligation is the service component of the Landis and Gyr contract.
	The quantified obligations are based on the FERC and NEB (National Energy Board) currently authorized rates, which are subject to change.
	Demand Charge Obligations	2014			2015			2016			2017			2018			Thereafter		Total
	(Dollars in Thousands)
	Firm transportation service	$	168,936		$	166,452		$	159,899		$	156,205		$	133,281		$	487,739	$	1,272,512
	Firm storage service	6,528			5,337			5,209			5,209			1,407			2,793		26,483
	Total	$	175,464		$	171,789		$	165,108		$	161,414		$	134,688		$	490,532	$	1,298,995
	These contracts have varying terms and may include escalation and termination provisions.
	(Dollars in Thousands)	2014			2015			2016			2017			2018			Thereafter		Total
	Columbia River projects	$	67,094		$	69,401		$	70,924		$	71,091		$	62,477		$	601,448	$	942,435
	Other utilities	17,277			16,718			17,229			10,174			—			—		61,398
	Non-utility contracts	53,928			116,317			150,305			186,948			191,405			1,480,584		2,179,487
	Total	$	138,299		$	202,436		$	238,458		$	268,213		$	253,882		$	2,082,032	$	3,183,320

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]	'
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]	'
	The following tables set forth the components of the Company’s accumulated other comprehensive income (loss) at:
	Puget Energy	December 31,
	(Dollars in Thousands)	2013			2012
	Net unrealized loss on energy derivative instruments	$	(705	)	$	(742	)
	Net unrealized loss on interest rate swaps	(94		)	(3,022		)
	Net unrealized loss and prior service cost on pension plans	48,514			(29,065		)
	Total Puget Energy, net of tax	$	47,715		$	(32,829	)
	Puget Sound Energy	December 31,
	(Dollars in Thousands)	2013			2012
	Net unrealized loss on energy derivative instruments	$	(2,027	)	$	(4,576	)
	Net unrealized loss on treasury interest rate swaps	(6,307		)	(6,624		)
	Net unrealized loss and prior service cost on pension plans	(87,405		)	(175,998		)
	Total PSE, net of tax	$	(95,739	)	$	(187,198	)
	The following tables present the changes in the Company’s accumulated other comprehensive income (loss) (AOCI) by component for the years ended December 31, 2013, 2012 and 2011, respectively.
	Puget Energy	Net unrealized gain (loss) on interest rate swaps			Net unrealized gain (loss) and prior service cost on pension plans			Net unrealized gain (loss) on energy derivative instruments
	Changes in AOCI, net of tax
	(Dollars in Thousands)										Total
	Balance at December 31, 2010	$	(40,041	)	$	39,630		$	(2,658	)	$	(3,069	)
	Other comprehensive income (loss) before reclassifications	—			(53,742		)	—			(53,742		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	25,442			(1,083		)	1,545			25,904
	Net current-period other comprehensive income (loss)	25,442			(54,825		)	1,545			(27,838		)
	Balance at December 31, 2011	$	(14,599	)	$	(15,195	)	$	(1,113	)	$	(30,907	)
	Other comprehensive income (loss) before reclassifications	—			(13,574		)	—			(13,574		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	11,577			(296		)	371			11,652
	Net current-period other comprehensive income (loss)	11,577			(13,870		)	371			(1,922		)
	Balance at December 31, 2012	$	(3,022	)	$	(29,065	)	$	(742	)	$	(32,829	)
	Other comprehensive income (loss) before reclassifications	—			76,004			—			76,004
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	2,928			1,575			37			4,540
	Net current-period other comprehensive income (loss)	2,928			77,579			37			80,544
	Balance at December 31, 2013	$	(94	)	$	48,514		$	(705	)	$	47,715
	Puget Sound Energy	Net unrealized gain (loss) and prior service cost on pension plans			Net unrealized gain (loss) on energy derivative instruments			Net unrealized gain (loss) on treasury interest rate swaps
	Changes in AOCI, net of tax
	(Dollars in Thousands)										Total
	Balance at December 31, 2010	$	(115,778	)	$	(34,612	)	$	(7,257	)	$	(157,647	)
	Other comprehensive income (loss) before reclassifications	(59,468		)	—			—			(59,468		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	6,542			21,678			316			28,536
	Net current-period other comprehensive income (loss)	(52,926		)	21,678			316			(30,932		)
	Balance at December 31, 2011	$	(168,704	)	$	(12,934	)	$	(6,941	)	$	(188,579	)
	Other comprehensive income (loss) before reclassifications	(17,049		)	—			—			(17,049		)
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	9,755			8,358			317			18,430
	Net current-period other comprehensive income (loss)	(7,294		)	8,358			317			1,381
	Balance at December 31, 2012	$	(175,998	)	$	(4,576	)	$	(6,624	)	$	(187,198	)
	Other comprehensive income (loss) before reclassifications	74,969			—			—			74,969
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	13,624			2,549			317			16,490
	Net current-period other comprehensive income (loss)	88,593			2,549			317			91,459
	Balance at December 31, 2013	$	(87,405	)	$	(2,027	)	$	(6,307	)	$	(95,739	)
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]	'
	Details about these reclassifications out of accumulated other comprehensive income (loss) for the years ended December 31, 2013, 2012 and 2011, respectively, are as follows:
	Puget Energy
	(Dollars in Thousands)
	Details about accumulated other comprehensive income (loss) components	Affected line item in the statement where net income (loss) is presented	Amount reclassified from accumulated
			other comprehensive income (loss)
			2013			2012			2011
	Net unrealized gain (loss) on interest rate swaps:
	Interest rate contracts	Interest expense	$	(4,505	)	$	(17,811	)	$	(39,143	)
		Tax (expense) or benefit	1,577			6,234			13,701
		Net of Tax	$	(2,928	)	$	(11,577	)	$	(25,442	)
	Net unrealized gain (loss) and prior service cost on pension plans:
	Amortization of prior service cost	(a)	1,997			1,980			1,980
	Amortization of net gain (loss)	(a)	(4,420		)	(1,524		)	(314		)
		Total before tax	(2,423		)	456			1,666
		Tax (expense) or benefit	848			(160		)	(583		)
		Net of Tax	$	(1,575	)	$	296		$	1,083
	Net unrealized gain (loss) on energy derivative instruments:
	Commodity contracts: Electric derivatives	Electric generation fuel	—			100			(679		)
		Purchased electricity	(57		)	(671		)	(1,698		)
		Total before tax	(57		)	(571		)	(2,377		)
		Tax (expense) or benefit	20			200			832
		Net of Tax	$	(37	)	$	(371	)	$	(1,545	)
	Total reclassification for the period	Net of Tax	$	(4,540	)	$	(11,652	)	$	(25,904	)
	__________
	(a)	These accumulated other comprehensive income components are included in the computation of net periodic pension cost (see Note 12 for additional details).
	Puget Sound Energy
	(Dollars in Thousands)
	Details about accumulated other comprehensive income (loss) components	Affected line item in the statement where net income (loss) is presented	Amount reclassified from accumulated
			other comprehensive income (loss)
			2013			2012			2011
	Net unrealized gain (loss) and prior service cost on pension plans:
	Amortization of prior service cost	(a)	$	1,559		$	1,245		$	949
	Amortization of net gain (loss)	(a)	(22,519		)	(16,203		)	(10,963		)
	Amortization of transition obligation	(a)	—			(50		)	(50		)
		Total before tax	(20,960		)	(15,008		)	(10,064		)
		Tax (expense) or benefit	7,336			5,253			3,522
		Net of tax	$	(13,624	)	$	(9,755	)	$	(6,542	)
	Net unrealized gain (loss) on energy derivative instruments:
	Commodity contracts: Electric derivatives	Electric generation fuel	—			97			(20,625		)
		Purchased electricity	(3,922		)	(12,955		)	(12,726		)
		Total before tax	(3,922		)	(12,858		)	(33,351		)
		Tax (expense) or benefit	1,373			4,500			11,673
		Net of Tax	$	(2,549	)	$	(8,358	)	$	(21,678	)
	Net unrealized gain (loss) on treasury interest rate swaps:
	Interest rate contracts	Interest expense	(488		)	(488		)	(488		)
		Tax (expense) or benefit	171			171			172
		Net of Tax	$	(317	)	$	(317	)	$	(316	)
	Total reclassification for the period	Net of Tax	$	(16,490	)	$	(18,430	)	$	(28,536	)
	__________
	(a)	These accumulated other comprehensive income components are included in the computation of net periodic pension cost (see Note 12 for additional details).

SUPPLEMENTAL_QUARTERLY_FINANCI1

SUPPLEMENTAL QUARTERLY FINANCIAL DATA (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Financial Information	'
	The following unaudited amounts, in the opinion of the Company, include all adjustments (consisting of normal recurring adjustments) necessary for a fair statement of the results of operations for the interim periods.  Quarterly amounts vary during the year due to the seasonal nature of the utility business.
	Puget Energy	2013 Quarter
	(Unaudited; Dollars in Thousands)	First		Second		Third		Fourth
	Operating revenue	$	999,818	$	642,486	$	598,348	$	946,645
	Operating income	317,735		95,081		100,043		242,301
	Net income	167,475		905		8,540		108,808
		2012 Quarter
	(Unaudited; Dollars in Thousands)	First		Second		Third		Fourth
	Operating revenue	$	1,048,512	$	678,617	$	578,755	$	909,272
	Operating income	209,023		159,876		153,262		193,374
	Net income (loss)	88,480		57,692		46,692		80,957
	Puget Sound Energy	2013 Quarter
	(Unaudited; Dollars in Thousands)	First		Second		Third		Fourth
	Operating revenue	$	999,707	$	642,486	$	598,348	$	946,794
	Operating income	310,587		91,094		96,085		237,808
	Net income	179,938		26,663		26,605		122,923
		2012 Quarter
	(Unaudited; Dollars in Thousands)	First		Second		Third		Fourth
	Operating revenue	$	1,048,512	$	678,617	$	579,611	$	909,519
	Operating income	201,245		153,306		150,007		188,431
	Net income (loss)	112,716		80,872		66,868		95,714

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details) (USD $)

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Feb. 06, 2009

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

unit

Electric Transmission

Electric Transmission

Electric Transmission

Gas Transmission Equipment

Gas Transmission Equipment

Gas Transmission Equipment

Common Plant

Common Plant

Common Plant

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

sqmi

Accounting Policies

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Area of service territory (sqmi)

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6,000

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Reclassification from AR to AP

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$33,700,000

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Public Utilities, Rate Case, Deferred Maintenance Costs Threshold

500,000

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Annual depreciation provision

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2.80%

2.90%

2.70%

3.40%

3.40%

3.50%

11.40%

11.60%

11.30%

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Recognition of goodwill due to merger

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1,700,000,000

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Number of reportable segments

1

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Cash and Cash Equivalents

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'

'

Cash and Cash Equivalents, at Carrying Value

44,302,000

135,542,000

37,235,000

36,557,000

'

'

'

'

'

'

'

'

'

'

44,111,000

135,530,000

31,010,000

36,320,000

Cash equivalents

2,600,000

107,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue Recognition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Excise taxes collected

'

'

'

'

'

'

'

'

'

'

'

'

'

'

243,900,000

244,200,000

252,500,000

'

Allowance for Doubtful Accounts

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allowance for doubtful accounts

7,385,000

9,932,000

'

'

'

'

'

'

'

'

'

'

'

'

7,385,000

9,932,000

'

'

Self Insurance [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public Utilities, Rate Case, Deferred Storm Costs Threshold

8,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Statements of Cash Flows

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital Lease Obligations Incurred

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$37,900,000

'

Summary_of_Significant_Account4

Summary of Significant Accounting Policies - AFUDC (Details)	6 Months Ended	12 Months Ended	14 Months Ended	25 Months Ended
	Dec. 31, 2013	Dec. 31, 2013	Jun. 30, 2013	13-May-12
Regulatory Assets [Line Items]	'	'	'	'
Public Utilities, Property, Plant and Equipment, Non-project Electric Utility Plant, Estimated Useful Life Average	'	'30 years	'	'
Washington Commission AFUDC Rates	7.77%	'	7.80%	8.10%

Summary_of_Significant_Account5

Summary of Significant Accounting Policies Cash Flow Restatement (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Regulatory assets	($122,549)	($170,374)	($64,173)
Net Cash Provided by (Used in) Operating Activities	766,068	782,685	915,923
Energy Efficiency Expenditures	'	0	0
Net Cash Provided by (Used in) Investing Activities	-480,918	-692,970	-982,410
Scenario, Previously Reported	'	'	'
Regulatory assets	'	-64,368	30,232
Net Cash Provided by (Used in) Operating Activities	'	888,691	1,010,328
Energy Efficiency Expenditures	'	-106,006	-94,405
Net Cash Provided by (Used in) Investing Activities	'	-798,976	-1,076,815
PUGET SOUND ENERGY, INC.	'	'	'
Regulatory assets	-122,549	-170,374	-65,134
Net Cash Provided by (Used in) Operating Activities	835,679	797,882	809,017
Energy Efficiency Expenditures	'	0	0
Net Cash Provided by (Used in) Investing Activities	-479,798	-672,069	-966,183
PUGET SOUND ENERGY, INC. | Scenario, Previously Reported	'	'	'
Regulatory assets	'	-64,368	29,271
Net Cash Provided by (Used in) Operating Activities	'	903,888	903,422
Energy Efficiency Expenditures	'	-106,006	-94,405
Net Cash Provided by (Used in) Investing Activities	'	($778,075)	($1,060,588)

Summary_of_Significant_Account6

Summary of Significant Accounting Policies - Accumulated Other Comprehensive Income (Loss) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Accumulated Other Comprehensive Income (Loss)	'	'
Net unrealized loss on energy derivative instruments	($705)	($742)
Net unrealized loss on interest rate swaps	-94	-3,022
Net unrealized loss and prior service cost on pension plans	48,514	-29,065
Accumulated other comprehensive income (loss), net of tax	47,715	-32,829
PUGET SOUND ENERGY, INC.	'	'
Accumulated Other Comprehensive Income (Loss)	'	'
Net unrealized loss on energy derivative instruments	-2,027	-4,576
Net unrealized loss on interest rate swaps	-6,307	-6,624
Net unrealized loss and prior service cost on pension plans	-87,405	-175,998
Accumulated other comprehensive income (loss), net of tax	($95,739)	($187,198)

Regulation_and_Rates_Schedule_

Regulation and Rates Schedule of Allowed Return on the Net Regulatory Assets and Liabilities (Details)	6 Months Ended	14 Months Ended	25 Months Ended
	Dec. 31, 2013	Jun. 30, 2013	13-May-12
Regulated Operations [Abstract]	'	'	'
Regulated Utility, Allowed Rate of Return on Net Regulatory Assets and Liabilities	7.77%	7.80%	8.10%
Regulated Utlity, After-tax Allowed Rate of Return on Net Regulatory Assets and Liabilities	6.69%	6.71%	6.90%

Regulation_and_Rates_Net_regul

Regulation and Rates Net regulatory assets and liabilities (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
PUGET SOUND ENERGY, INC. | Cost of removal	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	($269,536)	[1]	($239,243)	[1]
PUGET SOUND ENERGY, INC. | Deferred income taxes	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-93,618	[2]	-93,618	[2]
PUGET SOUND ENERGY, INC. | PGA payable	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-5,938		-32,587
Remaining Amortization Period	'1 year		'
PUGET SOUND ENERGY, INC. | PCA mechanism	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-5,345	[3]	0	[3]
PUGET SOUND ENERGY, INC. | Decoupling over-collection	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-20,535	[3]	0	[3]
PUGET SOUND ENERGY, INC. | Summit purchase option buy-out	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-10,763		-12,338
Remaining Amortization Period	'6 years 9 months		'
PUGET SOUND ENERGY, INC. | Deferred gain on Jefferson County sale	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-60,844	[3]	0	[3]
PUGET SOUND ENERGY, INC. | Deferred credit on Biogas sale	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-10,908		0
Remaining Amortization Period	'1 year		'
PUGET SOUND ENERGY, INC. | Deferred credit on gas pipeline capacity	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-4,508		-6,213
Net Regulatory Assets, Remaining Amortization Period, Max	'4 years 10 months		'
PUGET SOUND ENERGY, INC. | Renewable energy credits	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-5,820	[3]	-11,341	[3]
PUGET SOUND ENERGY, INC. | Treasury grants	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-203,889		-225,573
Net Regulatory Assets, Remaining Amortization Period, Min	'6 years		'
Net Regulatory Assets, Remaining Amortization Period, Max	'9 years		'
PUGET SOUND ENERGY, INC. | Various other regulatory liabilities	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-5,755		-7,998
Net Regulatory Assets, Remaining Amortization Period, Max	'4 years		'
PUGET SOUND ENERGY, INC. | Liabilities, Total	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-697,459	[4]	-628,911	[4]
PUGET SOUND ENERGY, INC. | Net Regulatory Assets	'		'
Regulatory Assets [Line Items]	'		'
Net Regulatory Assets	198,273		307,312
PUGET SOUND ENERGY, INC. | PGA deferral of unrealized losses on derivative instruments	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	27,555	[3]	95,953	[3]
PUGET SOUND ENERGY, INC. | Chelan PUD contract initiation	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	126,404		133,492
Remaining Amortization Period	'17 years 9 months		'
PUGET SOUND ENERGY, INC. | Storm damage costs electric	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	116,328		131,904
Net Regulatory Assets, Remaining Amortization Period, Min	'1 year		'
Net Regulatory Assets, Remaining Amortization Period, Max	'5 years		'
PUGET SOUND ENERGY, INC. | Environmental remediation	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	57,342	[3]	66,402	[3]
PUGET SOUND ENERGY, INC. | Baker Dam licensing operating and maintenance costs	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	57,270		57,644
Remaining Amortization Period	'45 years		'
PUGET SOUND ENERGY, INC. | Snoqualmie Licensing Operating Maintenance Costs	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	10,881		7,816
Remaining Amortization Period	'31 years		'
PUGET SOUND ENERGY, INC. | Colstrip common property	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	7,479		8,195
Remaining Amortization Period	'10 years 6 months		'
PUGET SOUND ENERGY, INC. | Deferred income taxes	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	146,350	[3]	119,279	[3]
PUGET SOUND ENERGY, INC. | Deferred Washington Commission AFUDC	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	55,495		55,896
Net Regulatory Assets, Remaining Amortization Period, Max	'36 years		'
PUGET SOUND ENERGY, INC. | Energy conservation costs	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	35,987		26,940
Net Regulatory Assets, Remaining Amortization Period, Min	'1 year		'
Net Regulatory Assets, Remaining Amortization Period, Max	'2 years		'
PUGET SOUND ENERGY, INC. | Unamortized loss on reacquired debt	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	37,832		31,399
Net Regulatory Assets, Remaining Amortization Period, Min	'1 year		'
Net Regulatory Assets, Remaining Amortization Period, Max	'22 years 6 months		'
PUGET SOUND ENERGY, INC. | White River relicensing and other costs	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	28,190	[3]	29,654	[3]
PUGET SOUND ENERGY, INC. | Mint Farm ownership and operating costs	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	22,320		24,321
Remaining Amortization Period	'11 years 4 months		'
PUGET SOUND ENERGY, INC. | Investment in Bonneville Exchange power contract	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	12,343		15,870
Remaining Amortization Period	'3 years 6 months		'
PUGET SOUND ENERGY, INC. | Ferndale	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	22,811		1,789
Remaining Amortization Period	'5 years 9 months		'
PUGET SOUND ENERGY, INC. | Lower Snake River	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	92,924		126,887
Net Regulatory Assets, Remaining Amortization Period, Min	'2 years 4 months		'
Net Regulatory Assets, Remaining Amortization Period, Max	'23 years 4 months		'
PUGET SOUND ENERGY, INC. | Snoqualmie	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	8,009		0
Remaining Amortization Period	'5 years 9 months		'
PUGET SOUND ENERGY, INC. | Property tax tracker	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	22,134	[3]	0	[3]
PUGET SOUND ENERGY, INC. | Various other regulatory assets	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	8,078		2,782
PUGET SOUND ENERGY, INC. | Assets, Total	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	895,732	[4]	936,223	[4]
PUGET ENERGY | Regulatory liabilities related to power contracts	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-443,065		-507,009
Net Regulatory Assets, Remaining Amortization Period, Min	'1 year		'
Net Regulatory Assets, Remaining Amortization Period, Max	'38 years		'
PUGET ENERGY | Various other regulatory liabilities	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-2,884		-4,373
PUGET ENERGY | Liabilities, Total	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Liabilities	-1,143,408		-1,140,293
PUGET ENERGY | Net Regulatory Assets	'		'
Regulatory Assets [Line Items]	'		'
Net Regulatory Assets	-213,406		-163,236
PUGET ENERGY | Requlatory Assets Related to Power Contracts	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	33,753		37,655
Net Regulatory Assets, Remaining Amortization Period, Min	'1 year		'
Net Regulatory Assets, Remaining Amortization Period, Max	'23 years		'
PUGET ENERGY | Various other regulatory assets	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	517		3,179
PUGET ENERGY | Assets, Total	'		'
Regulatory Assets [Line Items]	'		'
Regulatory Assets	$930,002		$977,057
[1]	The balance is dependent upon the cost of removal of underlying assets and the life of utility plant.
[2]	Amortization will begin once PTCs are utilized by PSE on its tax return.
[3]	Amortization periods vary depending on timing of underlying transactions or awaiting regulatory approval in a future Washington Commission rate proceeding.
[4]	Puget Energy’s regulatory assets and liabilities include purchase accounting adjustments under ASC 805 as a result of the merger.

Regulation_and_Rates_Rate_Adju

Regulation and Rates Rate Adjustments (Details) (USD $)

Jul. 01, 2013

14-May-12

Nov. 01, 2013

Jul. 01, 2013

Jan. 02, 2014

Jul. 01, 2013

14-May-12

Nov. 01, 2010

Jun. 28, 2012

14-May-12

Jul. 01, 2013

Jan. 02, 2014

Jul. 01, 2013

14-May-12

Apr. 02, 2011

Nov. 01, 2013

Nov. 01, 2012

Nov. 01, 2011

Mar. 30, 2013

Mar. 30, 2013

Mar. 30, 2013

In Millions, unless otherwise specified

Electric

Electric

Electric

Electric

Electric

Electric

Electric

Gas

Gas

Gas

Gas

Gas

Gas

Gas

Gas

Gas

Gas

Jefferson County Public Utility District

PUGET SOUND ENERGY, INC.

Customers

Power Cost Only Rate Case (PCORC)

Decoupling Mechanism

Expedited Rate Filing

Expedited Rate Filing

General Rate Case

Production Tax Credit

Decoupling Mechanism

Expedited Rate Filing

Expedited Rate Filing

General Rate Case

General Rate Case

Purchased Gas Adjustment (PGA)

Purchased Gas Adjustment (PGA)

Purchased Gas Adjustment (PGA)

Jefferson County Public Utility District

Jefferson County Public Utility District

Regulation and Rates [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public Utilities, Rate Case, Approved Effective Annual Rate Increase (Decrease)

'

'

$10.50

($21.40)

'

($30.70)

($63.30)

$27.70

'

'

($10.80)

'

$2

($13.40)

($19)

($4)

$77

$43.50

'

'

'

Public Utilities, Rate Case, Approved Effective Annual Rate Percentage Increase (Decrease)

'

'

-0.50%

1.00%

3.00%

1.50%

3.20%

-2.90%

'

'

1.10%

2.20%

-0.20%

1.30%

1.80%

0.40%

-7.70%

-4.30%

'

'

'

Public Utilities, Rate Case, Approved Effective Weighted Cost of Capital

7.77%

7.80%

'

'

'

'

'

'

'

7.80%

'

'

'

'

'

'

'

'

'

'

'

Public Utilities, Rate Case, Approved Effective Common Equity in Capital Structure

48.00%

48.00%

'

'

'

'

'

'

'

48.00%

'

'

'

'

'

'

'

'

'

'

'

Public Utilities, Rate Case, Approved Effective Return on Equity

9.80%

9.80%

'

'

'

'

'

'

'

9.80%

'

'

'

'

'

'

'

'

'

'

'

Property, Plant and Equipment, Net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

46.7

'

'

Significant Acquisitions and Disposals, Gain (Loss) on Sale or Disposal, Pretax

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

60

45

15

Accounting Petition, Approved Effective Increase (Decrease) to Revenue

'

'

'

'

'

'

'

'

6.9

'

'

'

'

'

'

'

'

'

'

'

'

Accounting Petition, Approved Effective Increase (Decrease) to Conservation Amortization Expense

'

'

'

'

'

'

'

'

$6.60

'

'

'

'

'

'

'

'

'

'

'

'

Regulation_and_Rates_Power_Cos

Regulation and Rates Power Cost Adjustment Mechanism (Details)	Dec. 31, 2013
Plus/Minus $20 million | Customers’ Share	'
Regulation and Rates [Line Items]	'
Annual Power Cost Variability	0.00%
Plus/Minus $20 million | Company's Share	'
Regulation and Rates [Line Items]	'
Annual Power Cost Variability	100.00%
Plus/Minus $20 million - $40 million | Customers’ Share	'
Regulation and Rates [Line Items]	'
Annual Power Cost Variability	50.00%
Plus/Minus $20 million - $40 million | Company's Share	'
Regulation and Rates [Line Items]	'
Annual Power Cost Variability	50.00%
Plus/Minus $40 million - $120 million | Customers’ Share	'
Regulation and Rates [Line Items]	'
Annual Power Cost Variability	90.00%
Plus/Minus $40 million - $120 million | Company's Share	'
Regulation and Rates [Line Items]	'
Annual Power Cost Variability	10.00%
Plus/Minus $120 million | Customers’ Share	'
Regulation and Rates [Line Items]	'
Annual Power Cost Variability	95.00%
Plus/Minus $120 million | Company's Share	'
Regulation and Rates [Line Items]	'
Annual Power Cost Variability	5.00%

Regulation_and_Rates_Details

Regulation and Rates (Details) (USD $)

Dec. 31, 2013

Feb. 28, 2012

Nov. 09, 2009

Nov. 08, 2009

Dec. 31, 2013

Dec. 31, 2013

Jan. 31, 2013

Dec. 31, 2013

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

Dec. 22, 2009

Dec. 31, 2013

In Millions, unless otherwise specified

MW

MW

MW

Electric

Gas plant

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

Seattle, Washington [Member]

Regulation and Rates [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Liabilities Reclassified from Accumulated Depreciation

'

'

'

'

'

'

'

'

'

$269.50

$239.20

'

'

'

'

Public Utilities, Rate Case, Deferred Storm Costs Threshold

8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Storm Damage Costs Incurred During Period

'

'

'

'

'

'

'

'

'

9.5

71.5

'

'

'

'

Storm Damage Costs Deferred During Period

'

'

'

'

'

'

'

'

'

'

60.4

'

'

'

'

Facility Power Capacity

'

343

273

229

'

'

'

'

'

'

'

'

'

'

'

American Recovery and Reinvestment Tax Act of 2009, Grant Approved Amount

'

'

'

'

'

'

'

'

'

'

205.3

'

'

28.7

'

American Recovery and Reinvestment Tax Act of 2009, Grant, Amortization Period Included in Customer Pass Through

'

'

'

'

'

'

'

'11 months

'

'

'

'

'23 months

'

'

American Recovery and Reinvestment Tax Act of 2009, Grant, Overall Average Rate Reduction

'

'

'

'

'

'

'

2.76%

-0.26%

'

'

0.30%

'

'

'

American Recovery and Reinvestment Tax Act of 2009, Total Grant Pass Through Amount

'

'

'

'

'

'

'

'

58.5

'

'

'

'

'

'

American Recovery and Reinvestment Tax Act of 2009, Grant, Approved Pass Back Rate

'

'

'

'

'

'

'

'

'

'

'

0.1

'

'

'

American Recovery and Reinvestment Tax Act of 2009, Grant Amortization Period

'

'

'

'

'

'

'

'10 years

'

'

'

'

'

'

'

American Recovery and Reinvestment Tax Act of 2009, Grant Pass Through Amount

'

'

'

'

'

'

'

34.6

37.8

'

'

5.5

'

'

'

American Recovery and Reinvestment Tax Act of 2009, Grant Pass Through Interest Amount

'

'

'

'

'

'

2.4

23.8

20.6

'

'

'

'

'

'

Accrual for Environmental Loss Contingencies

'

'

'

'

9.1

31.3

'

'

'

'

'

'

'

'

19.4

Environmental Exit Costs, Reasonably Possible Additional Losses, Low Estimate

'

'

'

'

9.1

31.3

'

'

'

'

'

'

'

'

'

Environmental Exit Costs, Reasonably Possible Additional Losses, High Estimate

'

'

'

'

27.4

49.5

'

'

'

'

'

'

'

'

'

Environmental Expense and Liabilities

'

'

'

'

$12.30

$45.10

'

'

'

'

'

'

'

'

'

Dividend_Payment_Restrictions_

Dividend Payment Restrictions (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Parent [Line Items]	'
Retained Earnings, Unappropriated	$469.60
Dividends, Earnings Before Interest, Tax, Deprecation and Amortization Ratio, Threshold For Dividend Payment	2
Dividends, Earnings Before Interest, Tax, Deprecation and Amortization Ratio at Period End	2.9
PUGET SOUND ENERGY, INC.	'
Parent [Line Items]	'
Dividends, Common Equity Ratio, Threshold For Dividend Payment	44.00%
Dividends, Earnings Before Interest, Tax, Deprecation and Amortization Ratio, Threshold For Dividend Payment	3
Dividends, Common Equity Ratio at Period End	47.40%
Dividends, Earnings Before Interest, Tax, Deprecation and Amortization Ratio at Period End	4.4

Utility_Plant_Details

Utility Plant (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Minimum

Maximum

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

Public Utility, Property, Plant and Equipment

'

'

'

'

'

'

Distribution plant, Estimated Useful Life

'

'

'10 years

'50 years

'

'

Production plant, Estimated Useful Life

'

'

'25 years

'125 years

'

'

Transmission plant, Estimated Useful Life

'

'

'45 years

'65 years

'

'

General plant, Estimated Useful Life

'

'

'5 years

'35 years

'

'

Intangible plant (including capitalized software), Estimated Useful Life

'

'

'3 years

'50 years

'

'

Plant acquisition adjustment, Estimated Useful Life

'

'

'7 years

'30 years

'

'

Underground storage, Estimated Useful Life

'

'

'25 years

'60 years

'

'

Liquefied natural gas storage, Estimated Useful Life

'

'

'25 years

'45 years

'

'

Capital leases, net of accumulated amortization, Estimated Useful Life

'

'

'1 year

[1]

'5 years

[1]

'

'

Accumulated amortization of capital leases

$20,800,000

$13,300,000

'

'

$20,800,000

$13,300,000

Utility Plant

'

'

'

'

'

'

Distribution plant

4,448,451,000

4,276,123,000

'

'

6,127,732,000

5,993,055,000

Production plant

2,966,223,000

2,480,135,000

'

'

3,948,270,000

3,464,528,000

Transmission plant

1,043,605,000

984,018,000

'

'

1,162,929,000

1,108,104,000

General plant

504,965,000

445,982,000

'

'

599,156,000

543,195,000

Intangible plant (including capitalized software)

316,614,000

181,884,000

'

'

309,972,000

181,596,000

Plant acquisition adjustment

242,826,000

242,659,000

'

'

282,792,000

282,624,000

Underground storage

27,857,000

27,331,000

'

'

41,501,000

40,987,000

Liquefied natural gas storage

12,622,000

12,622,000

'

'

14,492,000

14,492,000

Plant held for future use

28,742,000

18,416,000

'

'

28,895,000

18,568,000

Recoverable cushion gas

8,655,000

8,655,000

'

'

8,655,000

8,655,000

Plant not classified

124,589,000

155,626,000

'

'

124,589,000

155,625,000

Capital leases, net of accumulated amortization

17,051,000

[1]

24,629,000

[1]

'

'

17,051,000

[1]

24,629,000

[1]

Less: Accumulated depreciation and amortization

-1,373,178,000

-1,067,424,000

'

'

-4,297,012,000

-4,045,402,000

Subtotal

8,369,022,000

7,790,656,000

'

'

8,369,022,000

7,790,656,000

Construction work in progress

310,318,000

766,035,000

'

'

310,318,000

766,035,000

Net utility plant

$8,679,340,000

$8,556,691,000

'

'

$8,679,340,000

$8,556,691,000

[1]

Accumulated amortization of capital leases at Puget Energy was $20.8 million in 2013 and $13.3 million in 2012. Accumulated amortization of capital leases at PSE was $20.8 million in 2013 and $13.3 million in 2012.

Utility_Plant_Jointly_Owned_Ut

Utility Plant - Jointly Owned Utility Plant (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Jointly Owned Utility Plant Interests	'	'
Asset Retirement Obligation, Liabilities Incurred	$350	$7,737
Colstrip Units 1 & 2	'	'
Jointly Owned Utility Plant Interests	'	'
Company’s Ownership Share	50.00%	'
Plant in Service at Cost	162,090	'
Accumulated Depreciation	-20,875	'
Colstrip Units 3 & 4	'	'
Jointly Owned Utility Plant Interests	'	'
Company’s Ownership Share	25.00%	'
Plant in Service at Cost	234,984	'
Accumulated Depreciation	-33,270	'
Colstrip Units 1 – 4 Common Facilities	'	'
Jointly Owned Utility Plant Interests	'	'
Plant in Service at Cost	83	'
Accumulated Depreciation	-17	'
Frederickson 1	'	'
Jointly Owned Utility Plant Interests	'	'
Company’s Ownership Share	49.85%	'
Plant in Service at Cost	61,785	'
Accumulated Depreciation	-4,255	'
PUGET SOUND ENERGY, INC. | Colstrip Units 1 & 2	'	'
Jointly Owned Utility Plant Interests	'	'
Plant in Service at Cost	297,494	'
Accumulated Depreciation	-156,278	'
PUGET SOUND ENERGY, INC. | Colstrip Units 3 & 4	'	'
Jointly Owned Utility Plant Interests	'	'
Plant in Service at Cost	513,992	'
Accumulated Depreciation	-312,278	'
PUGET SOUND ENERGY, INC. | Colstrip Units 1 – 4 Common Facilities	'	'
Jointly Owned Utility Plant Interests	'	'
Plant in Service at Cost	252	'
Accumulated Depreciation	-185	'
PUGET SOUND ENERGY, INC. | Frederickson 1	'	'
Jointly Owned Utility Plant Interests	'	'
Plant in Service at Cost	70,719	'
Accumulated Depreciation	($13,189)	'

Utility_Plant_Asset_Retirement

Utility Plant - Asset Retirement Obligation (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Asset retirement obligation at beginning of period	$45,496	$26,540
New asset retirement obligation recognized in the period	350	7,737
Liability settled in the period	-1,188	-2,960
Revisions in estimated cash flows	2,769	12,632
Accretion expense	1,260	1,547
Asset retirement obligation at end of period	$48,687	$45,496

LongTerm_Debt_Schedule_of_Long

Long-Term Debt (Schedule of Long-Term Debt Instruments) (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

23-May-13

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Senior secured credit facility

Senior secured credit facility

Senior Secured Note

Senior Secured Note

Senior Secured Note

Senior Secured Note

Senior Secured Note

Senior Secured Note

Senior Secured Note

Senior Secured Note

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

6.500% Senior Secured Note Due 2020

6.500% Senior Secured Note Due 2020

6.000% Senior Secured Note Due 2021

6.000% Senior Secured Note Due 2021

5.625% Senior Secured Note Due 2022

5.625% Senior Secured Note Due 2022

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Senior Notes and First Mortgage Bonds

Pollution Control Bonds

Pollution Control Bonds

Pollution Control Bonds

Pollution Control Bonds

Pollution Control Bonds

Pollution Control Bonds

Pollution Control Bonds

Pollution Control Bonds

Junior Subordinated Notes

Junior Subordinated Notes

Junior Subordinated Notes

Junior Subordinated Notes

Junior Subordinated Notes

6.830% Series Due 2013

6.830% Series Due 2013

6.900% Series Due 2013

6.900% Series Due 2013

7.350% Series Due 2015

7.350% Series Due 2015

7.360% Series Due 2015

7.360% Series Due 2015

5.197% Series Due 2015

5.197% Series Due 2015

6.750% Series Due 2016

6.750% Series Due 2016

5.500% Secured Promissory Note Due 2017

5.500% Secured Promissory Note Due 2017

6.740% Series Due 2018

6.740% Series Due 2018

7.150% Series Due 2025

7.150% Series Due 2025

7.200% Series Due 2025

7.200% Series Due 2025

7.020% Series Due 2027

7.020% Series Due 2027

7.000% Series Due 2029

7.000% Series Due 2029

3.900% Series Due 2031

3.900% Series Due 2031

5.483% Series Due 2035

5.483% Series Due 2035

6.724% Series Due 2036

6.724% Series Due 2036

6.274% Series Due 2037

6.274% Series Due 2037

5.757% Series Due 2039

5.757% Series Due 2039

5.795% Series Due 2040

5.795% Series Due 2040

5.764% Series Due 2040

5.764% Series Due 2040

4.434% Series Due 2041

4.434% Series Due 2041

5.638% Series Due 2041

5.638% Series Due 2041

4.700% Series Due 2051

4.700% Series Due 2051

3.900% Series Due 2031

4.000% Series Due 2031

4.000% Series Due 2031

5.000% Series Due 2031

5.000% Series Due 2031

5.100% Series Due 2031

5.100% Series Due 2031

6.974% Series Due 2067

6.974% Series Due 2067

6.500% Senior Secured Note Due 2020

6.000% Senior Secured Note Due 2021

5.625% Senior Secured Note Due 2022

Debt Instrument [Line Items]

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Stated interest rate percent

'

'

'

'

'

'

6.50%

'

6.00%

'

'

'

'

'

6.83%

'

6.90%

'

7.35%

'

7.36%

'

5.20%

'

6.75%

'

5.50%

'

6.74%

'

7.15%

'

7.20%

'

7.02%

'

7.00%

'

'

'

5.48%

'

6.72%

'

6.27%

'

5.76%

'

5.80%

'

5.76%

'

4.43%

'

5.64%

'

4.70%

'

'

3.90%

4.00%

'

5.00%

'

5.10%

'

6.97%

'

6.50%

6.00%

5.63%

Total PSE long-term debt

$5,462,272,000

'

$299,000,000

$434,000,000

'

'

$450,000,000

$450,000,000

$500,000,000

$500,000,000

$450,000,000

$450,000,000

$3,763,272,000

'

$0

$3,000,000

$0

$10,000,000

$10,000,000

$10,000,000

$2,000,000

$2,000,000

$150,000,000

$150,000,000

$250,000,000

$250,000,000

$2,412,000

[1]

$2,412,000

[1]

$200,000,000

$200,000,000

$15,000,000

$15,000,000

$2,000,000

$2,000,000

$300,000,000

$300,000,000

$100,000,000

$100,000,000

$138,460,000

$0

$250,000,000

$250,000,000

$250,000,000

$250,000,000

$300,000,000

$300,000,000

$350,000,000

$350,000,000

$325,000,000

$325,000,000

$250,000,000

$250,000,000

$250,000,000

$250,000,000

$300,000,000

$300,000,000

$45,000,000

$45,000,000

$161,900,000

'

$23,400,000

$0

$0

$138,460,000

$0

$23,400,000

$250,000,000

$250,000,000

'

'

'

Long Term Debt, Reconciliation, Fair Value Adjustment

-229,746,000

-264,017,000

'

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Unamortized discount on senior notes

'

'

'

'

-36,000

-41,000

'

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'

'

'

'

-14,000

-14,000

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'

Net PSE long-term debt

$5,232,476,000

$5,346,200,000

'

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'

'

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'

'

'

'

'

$3,763,258,000

$3,776,258,000

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[1]

Accumulated amortization of capital leases at Puget Energy was $20.8 million in 2013 and $13.3 million in 2012. Accumulated amortization of capital leases at PSE was $20.8 million in 2013 and $13.3 million in 2012.

LongTerm_Debt_Narrative_Detail

Long-Term Debt (Narrative) (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 10, 2012

Dec. 31, 2013

Dec. 31, 2012

Jun. 15, 2012

Feb. 28, 2009

Feb. 10, 2012

Dec. 06, 2010

Feb. 28, 2009

Dec. 31, 2013

Feb. 10, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 04, 2013

23-May-13

23-May-13

23-May-13

Dec. 31, 2013

Senior secured credit facility

Senior secured credit facility

Senior secured credit facility

Capital Expenditure Facility

Term Loan

Term Loan

Term Loan

Revolving Credit Facility

Revolving Credit Facility

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET ENERGY

Pollution Control Bonds

Pollution Control Bonds

Pollution Control Bonds

Pollution Control Bonds

5.010% Series Due 2031

3.910% Series Due 2031

Debt Instrument [Line Items]

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'

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'

'

'

Long-term debt

$5,462,272,000

'

'

'

$299,000,000

$434,000,000

'

'

'

'

$1,225,000,000

'

'

$3,763,272,000

'

'

'

$161,900,000

'

'

'

Stated interest rate percent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.01%

3.91%

'

Liabilities and Equity, Fair Value Adjustment

'

'

'

'

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'

'

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'

'

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'

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18,000,000

Outstanding amount for line of credit

'

'

'

'

'

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'

'

'

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299,000,000

'

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'

'

'

'

'

'

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Debt Instrument, Term

'

'

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'5 years

'

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'

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'5 years

'5 years

'

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'

'

'

'

'

'

'

'

Debt instrument amount issued

'

'

'

'

'

'

450,000,000

'

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'

'

'

'

'

'

'

'

'

'

'

'

Repayments of long-term debt

309,860,000

1,273,000,000

769,000,000

'

425,000,000

'

'

'

'

'

'

'

'

174,860,000

0

285,000,000

'

'

'

'

'

Current borrowing capacity of line of credit

'

'

'

1,000,000,000

'

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1,000,000,000

'

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'

'

800,000,000

'

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1,000,000,000

'

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'

'

Maximum brrowing cpacity

$1,300,000,000

'

'

'

$859,000,000

'

'

'

'

'

'

'

'

$1,450,000,000

'

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'

'

'

'

'

LongTerm_Debt_Schedule_of_Matu

Long-Term Debt (Schedule of Maturities of Long-Term Debt) (Details) (USD $)	Dec. 31, 2013
Maturities of Long-term Debt [Abstract]	'
2014	$0
2015	162,000,000
2016	250,000,000
2017	301,412,000
2018	200,000,000
Thereafter	4,548,860,000
Total long-term debt	5,462,272,000
PUGET SOUND ENERGY, INC.	'
Maturities of Long-term Debt [Abstract]	'
2014	0
2015	162,000,000
2016	250,000,000
2017	2,412,000
2018	200,000,000
Thereafter	3,148,860,000
Total long-term debt	3,763,272,000
PUGET ENERGY	'
Maturities of Long-term Debt [Abstract]	'
2014	0
2015	0
2016	0
2017	299,000,000
2018	0
Thereafter	1,400,000,000
Total long-term debt	$1,699,000,000

Liquidity_Facilities_and_Other1

Liquidity Facilities and Other Financing Arrangements (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Feb. 10, 2012

Dec. 31, 2013

Dec. 31, 2011

Feb. 10, 2012

Dec. 31, 2013

Feb. 04, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Feb. 04, 2013

Dec. 31, 2013

Feb. 04, 2013

Dec. 31, 2013

Feb. 04, 2013

Dec. 31, 2013

Feb. 10, 2012

Senior secured credit facility

Senior secured credit facility

Revolving Credit Facility

Revolving Credit Facility

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET ENERGY

facility

facility

Promissory Note with Puget Energy

Working Capital Needs

Energy Hedging Activities

Energy Hedging Activities

Letter of Credit

Senior secured credit facility

Senior secured credit facility

Working Capital Needs

Promissory Note with Puget Energy

Short-term Debt [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding amount for line of credit

'

'

'

'

'

'

$299,000,000

'

'

'

'

$29,598,000

'

$1,000,000

'

$162,000,000

'

'

'

Short-term debt

162,000,000

181,000,000

'

0

0

'

'

'

162,000,000

181,000,000

181,000,000

'

'

'

'

'

'

'

'

Weighted-average interest rate on short-term debt (percent)

'

'

'

'

'

'

'

'

3.93%

'

6.49%

'

'

'

'

'

'

'

'

Number of committed unsecured revolving credit facilities

'

'

'

'

'

'

'

2

3

'

'

'

'

'

'

'

'

'

'

Current borrowing capacity of line of credit

'

'

1,000,000,000

'

'

800,000,000

'

1,000,000,000

'

'

'

'

650,000,000

'

350,000,000

3,000,000

'

30,000,000

1,000,000,000

Current same-day borrowing capacity

'

'

'

'

'

'

'

75,000,000

'

'

'

'

'

'

'

'

'

'

'

Maximum brrowing cpacity

$1,300,000,000

'

'

'

'

'

'

'

$1,450,000,000

'

'

'

'

'

'

'

'

'

'

Maximum capitalization percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

65.00%

'

'

Basis spread on variable rate (percent)

'

'

'

'

'

1.75%

'

'

'

'

'

'

'

'

'

'

1.25%

0.25%

'

Commitment fee percentage on line of credit

'

'

'

'

'

'

'

0.18%

'

'

'

'

'

'

'

'

'

'

'

Debt instrument variable rate basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'one-month LIBOR

'

Commitment fee percentage for line of credit

'

'

'

'

'

0.30%

'

'

'

'

'

'

'

'

'

'

'

'

'

Leases_Schedule_of_Operating_L

Leases (Schedule of Operating Lease Expense) (Details) (PUGET SOUND ENERGY, INC., USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
PUGET SOUND ENERGY, INC.	'	'	'
Operating Leases, Rent Expense, Net [Abstract]	'	'	'
Operating lease expense net of sublease receipts	$29,392	$29,661	$24,789

Leases_Schedule_of_Future_Mini

Leases (Schedule of Future Minimum Lease Payments for Non-cancellable Leases) (Details) (PUGET SOUND ENERGY, INC., USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
PUGET SOUND ENERGY, INC.	'
Operating	'
2014	$16,603
2015	16,963
2016	18,922
2017	18,852
2018	16,051
Thereafter	68,847
Total minimum lease payments	156,238
Capital	'
2014	8,160
2015	8,160
2016	2,718
2017	0
2018	0
Thereafter	0
Total minimum lease payments	$19,038

Accounting_for_Derivative_Inst2

Accounting for Derivative Instruments and Hedging Activities (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013
Derivative [Line Items]	'
Expected losses reclassified to OCI related to cash flow hedges within twelve months	$700,000
Electric Portfolio	'
Derivative [Line Items]	'
Collateral Already Posted, Aggregate Fair Value	0
PUGET SOUND ENERGY, INC.	'
Derivative [Line Items]	'
Expected losses reclassified to OCI related to cash flow hedges within twelve months	2,100,000
PUGET ENERGY | Interest Rate Swap	'
Derivative [Line Items]	'
Number of interest rate derivatives held	2
External Credit Rating, Investment Grade | Electric Portfolio	'
Derivative [Line Items]	'
Percentage of derivatives with credit risk exposure	99.90%
External Credit Rating, Non Investment Grade | Electric Portfolio	'
Derivative [Line Items]	'
Percentage of derivatives with credit risk exposure	0.10%
Credit Rating | Electric Portfolio	'
Derivative [Line Items]	'
Collateral Already Posted, Aggregate Fair Value	0	[1]
Credit Rating | Natural Gas Portfolio	'
Derivative [Line Items]	'
Collateral Already Posted, Aggregate Fair Value	$1,000,000
[1]	Failure by PSE to maintain an investment grade credit rating from each of the major credit rating agencies provides counterparties a contractual right to demand collateral.

Accounting_for_Derivative_Inst3

Accounting for Derivative Instruments and Hedging Activities (Schedule of Derivative Assets and Liabilities) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
Derivative [Line Items]	'		'
Assets, Current	$18,867,000		$6,869,000
Assets, Long-term	7,733,000		14,814,000
Liabilities, Current	48,049,000		177,519,000
Liabilities, Long-term	38,162,000		83,276,000
PUGET ENERGY	'		'
Derivative [Line Items]	'		'
Liabilities, Current	6,584,000		6,571,000
Liabilities, Long-term	6,656,000		15,043,000
PUGET SOUND ENERGY, INC.	'		'
Derivative [Line Items]	'		'
Assets, Current	18,867,000		6,869,000
Assets, Long-term	7,733,000		14,814,000
Liabilities, Current	41,465,000		170,948,000
Liabilities, Long-term	31,523,000		68,323,000
Commodity Contract	'		'
Derivative [Line Items]	'		'
Derivative Asset, Fair Value, Gross Asset	26,600,000	[1]	21,683,000	[1]
Total derivative assets	26,600,000		21,683,000
Total derivative liabilities	72,988,000		239,271,000
Derivative Asset, Collateral, Obligation to Return Cash, Offset	0		0
Derivative, Collateral, Obligation to Return Securities	-19,491,000		-14,126,000
Derivative, Collateral, Obligation to Return Cash	0		0
Derivative Asset, Fair Value, Amount Offset Against Collateral	7,109,000		7,557,000
Derivative Liability, Fair Value, Gross Liability	72,988,000	[1]	239,271,000	[1]
Derivative Liability, Collateral, Right to Reclaim Cash, Offset	0	[2]	0
Derivative, Collateral, Right to Reclaim Securities	-19,491,000		-14,126,000
Derivative, Collateral, Right to Reclaim Cash	0	[2]	0
Derivative Liability, Fair Value, Amount Offset Against Collateral	53,497,000		225,145,000
Natural Gas Portfolio	'		'
Derivative [Line Items]	'		'
Offsetting regulatory assets	27,600,000		96,000,000
Interest Rate Contract	'		'
Derivative [Line Items]	'		'
Total derivative liabilities	13,223,000	[2]	21,524,000	[2]
Derivative Liability, Fair Value, Gross Liability	13,223,000	[1],[2]	21,524,000	[1],[2]
Derivative Liability, Collateral, Right to Reclaim Cash, Offset	'		0	[2]
Derivative, Collateral, Right to Reclaim Securities	0	[2]	0	[2]
Derivative, Collateral, Right to Reclaim Cash	'		0	[2]
Derivative Liability, Fair Value, Amount Offset Against Collateral	13,223,000	[2]	21,524,000	[2]
Not Designated as Hedging Instrument	'		'
Derivative [Line Items]	'		'
Total derivative assets	26,600,000	[3]	21,683,000	[3]
Total derivative liabilities	86,211,000	[4]	260,795,000	[4]
Not Designated as Hedging Instrument | PUGET ENERGY	'		'
Derivative [Line Items]	'		'
Assets, Current	18,867,000	[3]	6,869,000	[3]
Assets, Long-term	7,733,000	[3]	14,814,000	[3]
Liabilities, Current	48,049,000	[4]	177,519,000	[4]
Liabilities, Long-term	38,162,000	[4]	83,276,000	[4]
Not Designated as Hedging Instrument | Interest Rate Swap	'		'
Derivative [Line Items]	'		'
Derivative, Notional Amount	450,000,000	[5]	450,000,000	[5]
Total derivative assets	0	[3],[5]	0	[3],[5]
Total derivative liabilities	13,223,000	[4],[5]	21,524,000	[4],[5]
Not Designated as Hedging Instrument | Electric Generation Fuel	'		'
Derivative [Line Items]	'		'
Derivative, Nonmonetary Notional Amount	145,600,000		129,700,000
Not Designated as Hedging Instrument | Purchased Electricity	'		'
Derivative [Line Items]	'		'
Derivative, Nonmonetary Notional Amount	8,600,000		10,700,000
Not Designated as Hedging Instrument | Electric Portfolio	'		'
Derivative [Line Items]	'		'
Total derivative assets	18,479,000	[3]	9,557,000	[3]
Total derivative liabilities	37,312,000	[4]	131,193,000	[4]
Not Designated as Hedging Instrument | Natural Gas Portfolio	'		'
Derivative [Line Items]	'		'
Total derivative assets	8,121,000	[3],[6]	12,126,000	[3],[6]
Total derivative liabilities	$35,676,000	[4],[6]	$108,078,000	[4],[6]
Not Designated as Hedging Instrument | Gas Derivatives	'		'
Derivative [Line Items]	'		'
Derivative, Nonmonetary Notional Amount	423,500,000	[6]	516,900,000	[6]
[1]	All Derivative Contract deals are executed under ISDA, NAESB and WSPP Master Netting Agreements with Right of Offset.
[2]	Interest Rate Swap Contracts are only held at Puget Energy.
[3]	Balance sheet location: Current and Long-term Unrealized gain on derivative instruments.
[4]	Balance sheet location: Current and Long-term Unrealized loss on derivative instruments.
[5]	Interest rate swap contracts are only held at Puget Energy.
[6]	PSE had a net derivative liability and an offsetting regulatory asset of $27.6 million at December 31, 2013 and $96.0 million at December 31, 2012 related to contracts used to economically hedge the cost of physical gas purchased to serve natural gas customers. All fair value adjustments on derivatives relating to the natural gas business have been deferred in accordance with ASC 980, due to the PGA mechanism.

Accounting_for_Derivative_Inst4

Accounting for Derivative Instruments and Hedging Activities (Schedule of Amounts Recognized in Statement of Income) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	($102,744)		($133,606)		$11,494
PUGET SOUND ENERGY, INC.	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	-98,880		-119,120		54,146
Not Designated as Hedging Instrument | Interest Rate Contract | Other Income (Deductions)	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	-2,420		4,288		28,601
Not Designated as Hedging Instrument | Interest Rate Contract | Interest Expense	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	5,904		29,727		46,045
Not Designated as Hedging Instrument | Commodity Contract | Unrealized (Gain) Loss on Derivative Instruments, Net	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	-102,744	[1]	-131,407	[1]	23,171	[1]
Not Designated as Hedging Instrument | Commodity Contract | Electric Generation Fuel	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	27,008		66,762		98,208
Not Designated as Hedging Instrument | Commodity Contract | Purchased Electricity	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	38,299		138,551		66,845
Not Designated as Hedging Instrument | PUGET ENERGY	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	-33,953		107,921		262,870
Not Designated as Hedging Instrument | PUGET SOUND ENERGY, INC.	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	-33,573		86,193		219,199
Not Designated as Hedging Instrument | PUGET SOUND ENERGY, INC. | Commodity Contract | Unrealized (Gain) Loss on Derivative Instruments, Net	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	-98,880		-119,120		54,146
Not Designated as Hedging Instrument | PUGET SOUND ENERGY, INC. | Commodity Contract | Electric Generation Fuel	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	27,008		66,762		98,208
Not Designated as Hedging Instrument | PUGET SOUND ENERGY, INC. | Commodity Contract | Purchased Electricity	'		'		'
Derivative Instruments, (Loss) Gain [Line Items]	'		'		'
Unrealized (gain) loss on derivative instruments	$38,299		$138,551		$66,845
[1]	For 2012 and 2011, the amounts differ from the amounts stated in the statements of income as they do not include amortization related to contracts that were recorded at fair value at the time of the February 2009 merger and subsequently designated as NPNS of $2.2 million for the year ended December 31, 2012 and $11.7 million for the year ended December 31, 2011.

Accounting_for_Derivative_Inst5

Accounting for Derivative Instruments and Hedging Activities (Schedule of Amounts Recognized in Other Comprehensive Income) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Interest Expense, Debt	$392,264	$392,216	$371,910
Purchased electricity	541,905	622,288	771,405
PUGET ENERGY	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Interest Expense, Debt	103,372	135,312	131,702
PUGET SOUND ENERGY, INC.	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Interest Expense, Debt	261,264	246,811	231,212
Purchased electricity	541,905	622,288	771,983
Cash Flow Hedging | PUGET ENERGY	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	-4,562	-18,382	-41,520
Cash Flow Hedging | PUGET SOUND ENERGY, INC.	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	-4,410	-13,346	-33,839
Reclassification out of Accumulated Other Comprehensive Income | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] | PUGET ENERGY | Interest Rate Contract	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Interest Expense, Debt	-4,505	-17,811	-39,143
Reclassification out of Accumulated Other Comprehensive Income | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] | PUGET ENERGY | Energy Related Derivative	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Purchased electricity	-57	-671	-1,698
Reclassification out of Accumulated Other Comprehensive Income | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] | PUGET SOUND ENERGY, INC. | Interest Rate Contract	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Interest Expense, Debt	-488	-488	-488
Electric Generation Fuel | Cash Flow Hedging | PUGET ENERGY	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	0	100	-679
Electric Generation Fuel | Cash Flow Hedging | PUGET SOUND ENERGY, INC.	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	0	97	-20,625
Purchased Electricity | Reclassification out of Accumulated Other Comprehensive Income | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] | Cash Flow Hedging | PUGET SOUND ENERGY, INC.	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Purchased electricity	($3,922)	($12,955)	($12,726)

Accounting_for_Derivative_Inst6

Accounting for Derivative Instruments and Hedging Activities (Schedule of Effects of Non-hedging Derivative Instuments on Income) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	$102,744,000		$133,606,000		($11,494,000)
Derivative contracts classified as financing activities due to merger	-34,250,000		-92,681,000		-182,710,000
Other Comprehensive Income Reclassification Of Net Unrealized Gain Loss On Interest Rate Swaps During Period Net Of Tax	2,928,000		11,577,000		25,443,000
Not Designated as Hedging Instrument | Interest Rate Contract | Other Deductions	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	2,420,000		-4,288,000		-28,601,000
Not Designated as Hedging Instrument | Interest Rate Contract | Interest Expense	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	-5,904,000		-29,727,000		-46,045,000
Not Designated as Hedging Instrument | Commodity contracts: | Unrealized (Gain) Loss on Derivative Instruments, Net	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	102,744,000	[1]	131,407,000	[1]	-23,171,000	[1]
Not Designated as Hedging Instrument | Commodity contracts: | Electric Generation Fuel	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	-27,008,000		-66,762,000		-98,208,000
Not Designated as Hedging Instrument | Commodity contracts: | Purchased Electricity	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	-38,299,000		-138,551,000		-66,845,000
PUGET ENERGY	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Derivative Instruments, Amount Not Designated as Normal Purchase, Normal Sale	'		-2,200,000		-11,700,000
PUGET ENERGY | Not Designated as Hedging Instrument	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	33,953,000		-107,921,000		-262,870,000
PUGET SOUND ENERGY, INC.	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	98,880,000		119,120,000		-54,146,000
PUGET SOUND ENERGY, INC. | Not Designated as Hedging Instrument	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	33,573,000		-86,193,000		-219,199,000
PUGET SOUND ENERGY, INC. | Not Designated as Hedging Instrument | Commodity contracts: | Unrealized (Gain) Loss on Derivative Instruments, Net	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	98,880,000		119,120,000		-54,146,000
PUGET SOUND ENERGY, INC. | Not Designated as Hedging Instrument | Commodity contracts: | Electric Generation Fuel	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	-27,008,000		-66,762,000		-98,208,000
PUGET SOUND ENERGY, INC. | Not Designated as Hedging Instrument | Commodity contracts: | Purchased Electricity	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Total gain (loss) recognized in income on derivatives	-38,299,000		-138,551,000		-66,845,000
Revolving Credit Facility | PUGET ENERGY	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Line of Credit Facility, Decrease, Repayments	135,000,000		'		'
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] | Revolving Credit Facility | PUGET ENERGY | Interest Rate Contract	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Other Comprehensive Income Reclassification Of Net Unrealized Gain Loss On Interest Rate Swaps During Period Net Of Tax	$700,000		'		'
[1]	For 2012 and 2011, the amounts differ from the amounts stated in the statements of income as they do not include amortization related to contracts that were recorded at fair value at the time of the February 2009 merger and subsequently designated as NPNS of $2.2 million for the year ended December 31, 2012 and $11.7 million for the year ended December 31, 2011.

Accounting_for_Derivative_Inst7

Accounting for Derivative Instruments and Hedging Activities (Schedule of Contractual Contingent Liability Positions) (Details) (Electric Portfolio, USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative [Line Items]	'
Fair Value Liability	($35,025)	[1]
Collateral Already Posted, Aggregate Fair Value	0
Contingent Collateral	12,561
Credit Rating	'
Derivative [Line Items]	'
Fair Value Liability	-12,561	[1],[2]
Collateral Already Posted, Aggregate Fair Value	0	[2]
Contingent Collateral	12,561	[2]
Requested Credit for Adequate Assurance	'
Derivative [Line Items]	'
Fair Value Liability	-22,415	[1]
Collateral Already Posted, Aggregate Fair Value	0
Contingent Collateral	0
Forward Value of Contract	'
Derivative [Line Items]	'
Fair Value Liability	-49	[1],[3]
Collateral Already Posted, Aggregate Fair Value	0	[3]
Contingent Collateral	$0	[3]
[1]	Represents the derivative fair value of contracts with contingent features for counterparties in net derivative liability positions. Excludes NPNS, accounts payable and accounts receivable.
[2]	Failure by PSE to maintain an investment grade credit rating from each of the major credit rating agencies provides counterparties a contractual right to demand collateral.
[3]	Collateral requirements may vary, based on changes in the forward value of underlying transactions relative to contractually defined collateral thresholds.

Fair_Value_Measurements_Assets

Fair Value Measurements - Assets and Liabilities Measured on Recurring Basis (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Commodity Contract	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	$26,600		$21,683
Fair Value, Measurements, Recurring | PUGET ENERGY | Level 2	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Liabilities	13,223		21,524
Fair Value, Measurements, Recurring | PUGET ENERGY | Level 2 | Interest Rate Contract	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Liabilities	13,223		21,524
Fair Value, Measurements, Recurring | PUGET ENERGY | Level 3	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring | PUGET ENERGY | Level 3 | Interest Rate Contract	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring | PUGET ENERGY | Level 3 | Commodity Contract | Electric Portfolio	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	3,818	[1]	'
Derivative Liabilities	19,239	[1]	'
Fair Value, Measurements, Recurring | PUGET ENERGY | Level 3 | Commodity Contract | Natural Gas Portfolio	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	2,673	[1]	'
Derivative Liabilities	3,034	[1]	'
Fair Value, Measurements, Recurring | PUGET ENERGY | Total	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Liabilities	13,223		21,524
Fair Value, Measurements, Recurring | PUGET ENERGY | Total | Interest Rate Contract	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Liabilities	13,223		21,524
Fair Value, Measurements, Recurring | PUGET SOUND ENERGY, INC. | Level 2	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	20,109		8,028
Derivative Liabilities	50,715		190,090
Fair Value, Measurements, Recurring | PUGET SOUND ENERGY, INC. | Level 2 | Commodity Contract | Electric Portfolio	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	14,661		1,259
Derivative Liabilities	18,073		88,971
Fair Value, Measurements, Recurring | PUGET SOUND ENERGY, INC. | Level 2 | Commodity Contract | Natural Gas Portfolio	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	5,448		6,769
Derivative Liabilities	32,642		101,119
Fair Value, Measurements, Recurring | PUGET SOUND ENERGY, INC. | Level 3	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	6,491		13,655
Derivative Liabilities	22,273		49,181
Fair Value, Measurements, Recurring | PUGET SOUND ENERGY, INC. | Level 3 | Commodity Contract | Electric Portfolio	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	'		8,298
Derivative Liabilities	'		42,221
Fair Value, Measurements, Recurring | PUGET SOUND ENERGY, INC. | Level 3 | Commodity Contract | Natural Gas Portfolio	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	'		5,357
Derivative Liabilities	'		6,960
Fair Value, Measurements, Recurring | PUGET SOUND ENERGY, INC. | Total	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	26,600		21,683
Derivative Liabilities	72,988		239,271
Fair Value, Measurements, Recurring | PUGET SOUND ENERGY, INC. | Total | Commodity Contract | Electric Portfolio	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	18,479		9,557
Derivative Liabilities	37,312		131,192
Fair Value, Measurements, Recurring | PUGET SOUND ENERGY, INC. | Total | Commodity Contract | Natural Gas Portfolio	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative Assets	8,121		12,126
Derivative Liabilities	35,676		108,079
Carrying Amount | PUGET ENERGY	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Cash and Cash Equivalents	44,302		135,542
Restricted Cash	7,171		3,700
Notes receivable and other	53,449		63,802
Total assets	104,922		203,044
Short Term Debt	162,000		181,000
Total liabilities	162,000		181,000
Carrying Amount | PUGET ENERGY | Level 1	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Cash and Cash Equivalents	44,302		135,542
Restricted Cash	7,171		3,700
Notes receivable and other	0		0
Total assets	51,473		139,242
Short Term Debt	162,000		181,000
Total liabilities	162,000		181,000
Carrying Amount | PUGET ENERGY | Level 2	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Cash and Cash Equivalents	0		0
Restricted Cash	0		0
Notes receivable and other	53,449		63,802
Total assets	53,449		63,802
Short Term Debt	0		0
Total liabilities	0		0
Carrying Amount | PUGET SOUND ENERGY, INC. | Level 1	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Cash and Cash Equivalents	44,111		135,530
Restricted Cash	7,171		3,700
Notes receivable and other	0		0
Total assets	51,282		139,230
Short Term Debt	162,000		181,000
Short-term debt owed by PSE to Puget Energy	0		0
Total liabilities	162,000		181,000
Carrying Amount | PUGET SOUND ENERGY, INC. | Level 2	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Cash and Cash Equivalents	0		0
Restricted Cash	0		0
Notes receivable and other	53,449		63,802
Total assets	53,449		63,802
Short Term Debt	0		0
Short-term debt owed by PSE to Puget Energy	29,598		29,598
Total liabilities	29,598		29,598
Carrying Amount | PUGET SOUND ENERGY, INC. | Total	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Cash and Cash Equivalents	44,111		135,530
Restricted Cash	7,171		3,700
Notes receivable and other	53,449		63,802
Total assets	104,731		203,032
Short Term Debt	162,000		181,000
Short-term debt owed by PSE to Puget Energy	29,598		29,598
Total liabilities	$191,598		$210,598
[1]	The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions.

Fair_Value_Measurements_Debt_a

Fair Value Measurements - Debt at Carrying and Fair Value (Details) (Income Approach Valuation Technique, USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
PUGET SOUND ENERGY, INC. | Carrying Amount	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	$3,763,258	$3,776,258
PUGET SOUND ENERGY, INC. | Carrying Amount | Level 2	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Junior subordinated notes	250,000	250,000
Long-term Debt, Fixed Rate, Net of Discount, Fair Value Disclosure	3,513,258	3,526,258
PUGET SOUND ENERGY, INC. | Total	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	4,307,821	4,893,351
PUGET SOUND ENERGY, INC. | Total | Level 2	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Junior subordinated notes	269,366	264,842
Long-term Debt, Fixed Rate, Net of Discount, Fair Value Disclosure	4,038,455	4,628,509
PUGET ENERGY | Carrying Amount	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	5,232,476	5,346,200
PUGET ENERGY | Carrying Amount | Level 2	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Junior subordinated notes	250,000	250,000
Long-term Debt, Fixed Rate, Net of Discount, Fair Value Disclosure	4,683,476	4,662,200
Long-term Debt, Variable Rate, Net of Discount, Fair Value Disclosure	299,000	434,000
PUGET ENERGY | Total	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	6,162,680	6,896,021
PUGET ENERGY | Total | Level 2	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Junior subordinated notes	269,366	264,842
Long-term Debt, Fixed Rate, Net of Discount, Fair Value Disclosure	5,594,314	6,197,179
Long-term Debt, Variable Rate, Net of Discount, Fair Value Disclosure	$299,000	$434,000

Fair_Value_Measurements_Unobse

Fair Value Measurements - Unobservable Input Reconciliation (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'		'		'
Balance at beginning of period	($35,526,000)		($95,352,000)		($91,295,000)
Included in earnings	-10,491,000	[1]	-21,362,000	[1]	-56,499,000	[1]
Included in regulatory assets / liabilities	-945,000		-1,937,000		-250,000
Settlements	10,855,000	[2]	60,102,000	[2]	37,482,000	[2]
Transferred into Level 3	-7,799,000		-55,845,000		-306,000
Transferred out of Level 3	28,124,000		78,868,000		15,516,000
Balance at end of period	-15,782,000		-35,526,000		-95,352,000
Electric Portfolio	'		'		'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'		'		'
Balance at beginning of period	-33,924,000		-90,311,000		-87,436,000
Included in earnings	-10,491,000	[1]	-21,362,000	[1]	-56,499,000	[1]
Included in regulatory assets / liabilities	0		0		0
Settlements	11,609,000	[2]	59,133,000	[2]	40,900,000	[2]
Transferred into Level 3	-7,799,000		-55,548,000		-759,000
Transferred out of Level 3	25,184,000		74,164,000		13,483,000
Balance at end of period	-15,421,000		-33,924,000		-90,311,000
Unrealized gain (loss) on derivative instruments, net	-13,400,000		-15,200,000		-55,200,000
Natural Gas Portfolio	'		'		'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'		'		'
Balance at beginning of period	-1,602,000		-5,041,000		-3,859,000
Included in earnings	0	[1]	0	[1]	0	[1]
Included in regulatory assets / liabilities	-945,000		-1,937,000		-250,000
Settlements	-754,000	[2]	969,000	[2]	-3,418,000	[2]
Transferred into Level 3	0		-297,000		453,000
Transferred out of Level 3	2,940,000		4,704,000		2,033,000
Balance at end of period	($361,000)		($1,602,000)		($5,041,000)
[1]	Income Statement location: Unrealized (gain) loss on derivative instruments, net. Includes unrealized gains (losses) on derivatives still held in position as of the reporting date for electric derivatives of $(13.4) million, $(15.2) million, and $(55.2) million for the years ended December 31, 2013, 2012 and 2011, respectively.
[2]	The Company had no purchases, sales or issuances during the reported periods.

Fair_Value_Measurements_Valuat

Fair Value Measurements - Valuation Techniques (Details) (USD $)

Dec. 31, 2013

Jul. 01, 2013

Mar. 30, 2012

Jun. 30, 2013

Dec. 31, 2012

Mar. 30, 2012

Jun. 30, 2013

Dec. 31, 2012

Mar. 30, 2012

Jun. 30, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jul. 01, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2011

Jul. 01, 2013

Mar. 31, 2012

Mar. 30, 2012

Mar. 31, 2012

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

PUGET ENERGY

PUGET ENERGY

Commodity Contract

Commodity Contract

Commodity Contract

Commodity Contract

Electric Portfolio

Electric Portfolio

Electric Portfolio

Natural Gas Portfolio

Natural Gas Portfolio

Natural Gas Portfolio

Priest Rapids Development

WNP-3 BPA Exchange Power Contract

Rock Island Project

Rock Island Project

Carrying Amount

Carrying Amount

Carrying Amount

Portion at Fair Value, Fair Value Disclosure

Minimum

Minimum

Minimum

Maximum

Maximum

Maximum

Weighted Average

Weighted Average

Weighted Average

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Electric Portfolio

Natural Gas Portfolio

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

Income Approach Valuation Technique

Level 3

Level 3

PUGET ENERGY

PUGET ENERGY

Minimum

Maximum

Weighted Average

Minimum

Maximum

Weighted Average

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Level 3

Level 3

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative assets

'

'

'

'

'

'

'

'

'

'

'

'

'

$26,600,000

$21,683,000

$3,818,000

[1]

$2,673,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative liabilities

'

'

'

'

'

'

'

'

'

'

'

0

0

'

'

19,239,000

[1]

3,034,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value Inputs, Price Per Megawatt-Hour

'

'

10.36

30.85

16.94

49.78

65.35

70.89

34.98

48.47

49.4

'

'

'

'

'

'

17.06

47.09

38.74

'

'

'

'

'

'

'

'

'

'

'

Fair Value Inputs, Price Per Millions of BTU

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.62

4.19

3.78

'

'

'

'

'

'

'

'

Fair Value measurement, sensitivity analysis, hypothetical increase or decrease of market prices, result on fair value, percent

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value Measurements, Sensitivity Analysis, Hypothetical Increase or Decrease of Market Prices, Result on Fair Value

-7,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Intangible asset fair value

'

484,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-10,200,000

33,600,000

113,300,000

96,700,000

13,500,000

Intangible asset carrying value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

47,100,000

16,600,000

'

'

'

'

'

'

Fair Value Inputs, Power Contract Costs

'

'

3,185,000

389,000

1,777,000

5,030,000

6,845,000

7,133,000

4,663,000

4,110,000

6,603,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Impairment of intangible assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$7,600,000

'

'

'

'

'

[1]

The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions.

Employee_Investment_Plans_Deta

Employee Investment Plans (Details) (PUGET SOUND ENERGY, INC., USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2011	Dec. 31, 2010
Defined Contribution Plan	'	'	'	'	'
Employer matching contribution, percent	1.00%	4.00%	'	'	'
Employer discretionary contribution amount	'	'	$14.60	$14.50	$13.50
6 percent	'	'	'	'	'
Defined Contribution Plan	'	'	'	'	'
Employer matching contribution, percent	'	4.50%	'	'	'
Maximum annual contribution per employee, percent	'	6.00%	'	'	'
Cash Balance Formula	'	'	'	'	'
Defined Contribution Plan	'	'	'	'	'
Employer matching contribution, percent	'	'	100.00%	'	'
Maximum annual contribution per employee, percent	'	'	6.00%	'	'
Employer additional contribution of base pay, percentage	'	'	1.00%	'	'
Cash Balance Formula | First 3 Percent	'	'	'	'	'
Defined Contribution Plan	'	'	'	'	'
Employer matching contribution, percent	'	100.00%	'	'	'
Maximum annual contribution per employee, percent	'	3.00%	'	'	'
Cash Balance Formula | Second 3 Percent	'	'	'	'	'
Defined Contribution Plan	'	'	'	'	'
Employer matching contribution, percent	'	50.00%	'	'	'
Maximum annual contribution per employee, percent	'	3.00%	'	'	'
Final Average Earnings Formula	'	'	'	'	'
Defined Contribution Plan	'	'	'	'	'
Employer matching contribution, percent	'	'	55.00%	'	'
Maximum annual contribution per employee, percent	'	'	6.00%	'	'

Retirement_Benefits_Change_in_

Retirement Benefits - Change in Net Benefit Obligation and Fair Value (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Qualified Pension Benefits	'	'	'
Change in benefit obligation:	'	'	'
Benefit obligation at beginning of period	$616,290	$565,997	'
Service cost	19,285	16,926	15,822
Interest cost	24,754	25,986	26,263
Amendment	0	0	'
Actuarial loss/(gain)	-48,559	40,914	'
Benefits paid	-38,453	-33,533	'
Medicare part D subsidy received	0	0	'
Benefit obligation at end of period	573,317	616,290	565,997
Change in plan assets:	'	'	'
Fair value of plan assets at beginning of period	531,183	479,786	'
Actual return on plan assets	102,591	62,130	'
Employer contribution	20,400	22,800	'
Benefits paid	-38,453	-33,533	'
Fair value of plan assets at end of period	615,721	531,183	479,786
Funded status at end of period	42,404	-85,107	'
SERP Pension Benefits	'	'	'
Change in benefit obligation:	'	'	'
Benefit obligation at beginning of period	51,795	48,370	'
Service cost	1,498	1,073	'
Interest cost	2,045	2,152	'
Amendment	478	-122	'
Actuarial loss/(gain)	-1,687	5,483	'
Benefits paid	-6,850	-5,161	'
Medicare part D subsidy received	0	0	'
Benefit obligation at end of period	47,279	51,795	'
Change in plan assets:	'	'	'
Fair value of plan assets at beginning of period	0	0	'
Actual return on plan assets	0	0	'
Employer contribution	6,850	5,161	'
Benefits paid	-6,850	-5,161	'
Fair value of plan assets at end of period	0	0	'
Funded status at end of period	-47,279	-51,795	'
Other Benefits	'	'	'
Change in benefit obligation:	'	'	'
Benefit obligation at beginning of period	17,672	16,436	'
Service cost	134	139	113
Interest cost	664	751	806
Amendment	0	0	'
Actuarial loss/(gain)	-2,240	1,199	'
Benefits paid	-1,536	-1,523	'
Medicare part D subsidy received	245	670	'
Benefit obligation at end of period	14,939	17,672	16,436
Change in plan assets:	'	'	'
Fair value of plan assets at beginning of period	7,541	7,206	'
Actual return on plan assets	1,861	1,100	'
Employer contribution	908	758	'
Benefits paid	-1,536	-1,523	'
Fair value of plan assets at end of period	8,774	7,541	7,206
Funded status at end of period	-6,165	-10,131	'
PUGET SOUND ENERGY, INC. | Qualified Pension Benefits	'	'	'
Change in benefit obligation:	'	'	'
Service cost	19,285	16,926	15,822
Interest cost	$24,753	$25,986	$26,263

Retirement_Benefits_Amounts_Re

Retirement Benefits - Amounts Recognized (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Qualified Pension Benefits	'	'
Defined Benefit Plan, Amounts Recognized in Statement of Financial Position Consist of: [Abstract]	'	'
Noncurrent assets	$42,404	$0
Current liabilities	0	0
Noncurrent liabilities	0	-85,107
Net assets / (liabilities)	42,404	-85,107
Other changes (pre-tax) in plan assets and benefit obligations recognized in other comprehensive income:	'	'
Net loss/(gain)	-112,055	14,988
Amortization of net (loss)/gain	-2,889	-768
Prior service cost/(credit)	0	0
Amortization of prior service cost/(credit)	1,980	1,980
Total change in other comprehensive income for year	-112,964	16,200
SERP Pension Benefits	'	'
Defined Benefit Plan, Amounts Recognized in Statement of Financial Position Consist of: [Abstract]	'	'
Noncurrent assets	0	'
Current liabilities	-3,981	-5,040
Noncurrent liabilities	-43,298	-46,755
Net assets / (liabilities)	-47,279	-51,795
Other changes (pre-tax) in plan assets and benefit obligations recognized in other comprehensive income:	'	'
Net loss/(gain)	-1,687	5,483
Amortization of net (loss)/gain	-1,461	-703
Prior service cost/(credit)	478	-122
Amortization of prior service cost/(credit)	17	0
Total change in other comprehensive income for year	-2,653	4,658
Other Benefits	'	'
Defined Benefit Plan, Amounts Recognized in Statement of Financial Position Consist of: [Abstract]	'	'
Noncurrent assets	0	'
Current liabilities	-421	-460
Noncurrent liabilities	-5,744	-9,671
Net assets / (liabilities)	-6,165	-10,131
Other changes (pre-tax) in plan assets and benefit obligations recognized in other comprehensive income:	'	'
Net loss/(gain)	-3,665	534
Amortization of net (loss)/gain	-70	-53
Prior service cost/(credit)	0	0
Amortization of prior service cost/(credit)	0	0
Total change in other comprehensive income for year	-3,735	481
PUGET ENERGY | Qualified Pension Benefits	'	'
Defined Benefit Plan, Amounts Recognized in Accumulated Other Comprehensive Income Consist of: [Abstract]	'	'
Net loss/(gain)	-65,943	49,001
Prior service cost/(credit)	-15,762	-17,741
Total	-81,705	31,260
PUGET ENERGY | SERP Pension Benefits	'	'
Defined Benefit Plan, Amounts Recognized in Accumulated Other Comprehensive Income Consist of: [Abstract]	'	'
Net loss/(gain)	9,670	12,818
Prior service cost/(credit)	373	-122
Total	10,043	12,696
PUGET ENERGY | Other Postretirement Benefit Plans, Defined Benefit	'	'
Defined Benefit Plan, Amounts Recognized in Accumulated Other Comprehensive Income Consist of: [Abstract]	'	'
Net loss/(gain)	-2,972	763
Prior service cost/(credit)	0	0
Total	-2,972	763
PUGET SOUND ENERGY, INC. | Qualified Pension Benefits	'	'
Defined Benefit Plan, Amounts Recognized in Accumulated Other Comprehensive Income Consist of: [Abstract]	'	'
Net loss/(gain)	138,324	269,401
Prior service cost/(credit)	-12,525	-14,098
Total	125,799	255,303
Other changes (pre-tax) in plan assets and benefit obligations recognized in other comprehensive income:	'	'
Net loss/(gain)	-110,465	20,318
Amortization of net (loss)/gain	-20,612	-15,015
Prior service cost/(credit)	0	0
Amortization of prior service cost/(credit)	1,573	1,573
Amortization of transition obligation	0	0
Total change in other comprehensive income for year	-129,504	6,876
PUGET SOUND ENERGY, INC. | SERP Pension Benefits	'	'
Defined Benefit Plan, Amounts Recognized in Accumulated Other Comprehensive Income Consist of: [Abstract]	'	'
Net loss/(gain)	14,050	17,928
Prior service cost/(credit)	383	-110
Total	14,433	17,818
Other changes (pre-tax) in plan assets and benefit obligations recognized in other comprehensive income:	'	'
Net loss/(gain)	-1,687	5,483
Amortization of net (loss)/gain	-2,191	-1,433
Prior service cost/(credit)	477	-122
Amortization of prior service cost/(credit)	16	-293
Amortization of transition obligation	0	0
Total change in other comprehensive income for year	-3,385	3,635
PUGET SOUND ENERGY, INC. | Other Benefits	'	'
Other changes (pre-tax) in plan assets and benefit obligations recognized in other comprehensive income:	'	'
Net loss/(gain)	-3,665	534
Amortization of net (loss)/gain	284	245
Prior service cost/(credit)	0	0
Amortization of prior service cost/(credit)	-30	-35
Amortization of transition obligation	0	-50
Total change in other comprehensive income for year	-3,411	694
PUGET SOUND ENERGY, INC. | Other Postretirement Benefit Plans, Defined Benefit	'	'
Defined Benefit Plan, Amounts Recognized in Accumulated Other Comprehensive Income Consist of: [Abstract]	'	'
Net loss/(gain)	-5,556	-2,175
Prior service cost/(credit)	6	36
Total	($5,550)	($2,139)

Retirement_Benefits_Net_Period

Retirement Benefits - Net Periodic Benefit Cost (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Qualified Pension Benefits	'	'	'
Components of net periodic benefit cost:	'	'	'
Service cost	$19,285	$16,926	$15,822
Interest cost	24,754	25,986	26,263
Expected return on plan assets	-39,095	-36,203	-35,344
Amortization of prior service cost/(credit)	-1,980	-1,980	-1,980
Amortization of net loss	2,889	768	0
Net periodic benefit cost	5,853	5,497	4,761
SERP Pension Benefits	'	'	'
Components of net periodic benefit cost:	'	'	'
Service cost	1,498	1,073	1,241
Interest cost	2,045	2,152	2,192
Amortization of prior service cost/(credit)	-17	0	0
Amortization of net loss	1,461	702	360
Net periodic benefit cost	4,987	3,927	3,793
Other Benefits	'	'	'
Components of net periodic benefit cost:	'	'	'
Service cost	134	139	113
Interest cost	664	751	806
Expected return on plan assets	-436	-435	-502
Amortization of prior service cost/(credit)	0	0	0
Amortization of net loss	69	53	-46
Net periodic benefit cost	431	508	371
PUGET SOUND ENERGY, INC. | Qualified Pension Benefits	'	'	'
Components of net periodic benefit cost:	'	'	'
Service cost	19,285	16,926	15,822
Interest cost	24,753	25,986	26,263
Expected return on plan assets	-40,685	-41,533	-44,128
Amortization of prior service cost/(credit)	-1,573	-1,573	-1,573
Amortization of net loss	20,612	15,015	10,250
Amortization of transition obligation	0	0	0
Net periodic benefit cost	22,392	14,821	6,634
PUGET SOUND ENERGY, INC. | SERP Pension Benefits	'	'	'
Components of net periodic benefit cost:	'	'	'
Service cost	1,498	1,073	1,241
Interest cost	2,045	2,152	2,192
Expected return on plan assets	0	0	0
Amortization of prior service cost/(credit)	-16	293	563
Amortization of net loss	2,191	1,432	1,194
Amortization of transition obligation	0	0	0
Net periodic benefit cost	5,718	4,950	5,190
PUGET SOUND ENERGY, INC. | Other Postretirement Benefit Plans, Defined Benefit	'	'	'
Components of net periodic benefit cost:	'	'	'
Service cost	134	139	113
Interest cost	664	751	806
Expected return on plan assets	-436	-435	-502
Amortization of prior service cost/(credit)	30	35	63
Amortization of net loss	-284	-245	-481
Amortization of transition obligation	0	50	50
Net periodic benefit cost	$108	$295	$49

Retirement_Benefits_Assumption

Retirement Benefits - Assumptions (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Benefit Obligation Assumptions	'		'		'
Discount rate	5.10%		'		'
Assumed Health Care Cost Trend Rates	'		'		'
Medical inflation rate assumed for next fiscal year	8.20%		'		'
Ultimate health care cost trend rate	4.30%		'		'
Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates	'		'		'
1% Increase, Effect on post-retirement benefit obligation	66		92		'
1% Decrease, Effect on post-retirement benefit obligation	-66		-92		'
1% Increase, Effect on service and interest cost components	3		4		'
1% Decrease, Effect on service and interest cost components	-3		-4		'
Qualified Pension Benefits	'		'		'
Benefit Obligation Assumptions	'		'		'
Discount rate	5.10%	[1]	4.15%	[1]	4.75%	[1]
Rate of compensation increase	4.50%		4.50%		4.50%
Medical trend rate	0.00%		0.00%		0.00%
Benefit Cost Assumptions	'		'		'
Discount rate	4.15%		4.75%		5.15%
Rate of plan assets	7.75%		7.75%		7.75%
Rate of compensation increase	4.50%		4.50%		4.50%
Medical trend rate	0.00%		0.00%		0.00%
SERP Pension Benefits	'		'		'
Benefit Obligation Assumptions	'		'		'
Discount rate	5.10%	[1]	4.15%	[1]	4.75%	[1]
Rate of compensation increase	4.50%		4.50%		4.50%
Medical trend rate	0.00%		0.00%		0.00%
Benefit Cost Assumptions	'		'		'
Discount rate	4.15%		4.75%		5.15%
Rate of plan assets	0.00%		0.00%		0.00%
Rate of compensation increase	4.50%		4.50%		4.50%
Medical trend rate	0.00%		0.00%		0.00%
Other Benefits	'		'		'
Benefit Obligation Assumptions	'		'		'
Discount rate	5.10%	[1]	4.15%	[1]	4.75%	[1]
Rate of compensation increase	4.50%		4.50%		4.50%
Medical trend rate	6.80%		7.50%		7.50%
Benefit Cost Assumptions	'		'		'
Discount rate	4.15%		4.75%		5.15%
Rate of plan assets	6.90%		7.50%		7.80%
Rate of compensation increase	4.50%		4.50%		4.50%
Medical trend rate	8.20%		7.50%		8.00%
[1]	The Company calculates the present value of the pension liability using a discount rate of 5.10% which represents the single-rate equivalent of the AA rated corporate bond yield curve.

Retirement_Benefits_Future_Ben

Retirement Benefits - Future Benefit Payments (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Qualified Pension Benefits	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
2014	$40,000
2015	40,200
2016	40,200
2017	41,100
2018	42,300
2019-2023	226,900
SERP Pension Benefits	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
2014	3,981
2015	1,985
2016	2,541
2017	1,900
2018	5,177
2019-2023	18,392
Other Benefits	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
2014	1,222
2015	1,193
2016	1,242
2017	1,197
2018	1,149
2019-2023	6,276
2014, without Medicare Part D subsidy	1,604
2015, without Medicare Part D subsidy	1,591
2016, without Medicare Part D subsidy	1,555
2017, without Medicare Part D subsidy	1,519
2018, without Medicare Part D subsidy	1,479
2019-2023, without Medicare Part D subsidy	$6,709

Retirement_Benefits_Plan_Asset

Retirement Benefits - Plan Asset Allocation (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

In Thousands, unless otherwise specified

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Other Benefits

Other Benefits

Other Benefits

SERP Pension Benefits

SERP Pension Benefits

SERP Pension Benefits

Domestic large cap equity

Domestic small cap equity

Non-U.S. equity

Fixed income

Real estate

Absolute return

Cash and cash equivalents

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Other Benefits

Other Benefits

Other Benefits

Other Benefits

Other Benefits

Other Benefits

Subtotal

Subtotal

Subtotal

Subtotal

Subtotal

Subtotal

Subtotal

Subtotal

Equities:

Equities:

Equities:

Equities:

Equities:

Equities:

Equities:

Equities:

Domestic large cap equity

Domestic large cap equity

Domestic large cap equity

Domestic large cap equity

Domestic large cap equity

Domestic large cap equity

Domestic large cap equity

Domestic large cap equity

Domestic small cap equity

Domestic small cap equity

Domestic small cap equity

Domestic small cap equity

Domestic small cap equity

Domestic small cap equity

Domestic small cap equity

Domestic small cap equity

Non-U.S. equity

Non-U.S. equity

Non-U.S. equity

Non-U.S. equity

Non-U.S. equity

Non-U.S. equity

Non-U.S. equity

Non-U.S. equity

Tactical asset allocation

Tactical asset allocation

Tactical asset allocation

Tactical asset allocation

Tactical asset allocation

Tactical asset allocation

Tactical asset allocation

Tactical asset allocation

Fixed income

Fixed income

Fixed income

Fixed income

Fixed income

Fixed income

Fixed income

Fixed income

Absolute return

Absolute return

Absolute return

Absolute return

Absolute return

Absolute return

Absolute return

Absolute return

Mutual Funds

Mutual Funds

Mutual Funds

Mutual Funds

Mutual Funds

Mutual Funds

Mutual Funds

Mutual Funds

Mutual Funds

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Cash and cash equivalents

Net (payable) receivable

Net (payable) receivable

Accrued income

Accrued income

Level 3

Level 3

Level 3

Total

Total

Level 1

Level 1

Level 2

Level 2

Total

Total

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Other Benefits

Other Benefits

Other Benefits

Other Benefits

Other Benefits

Other Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Other Benefits

Other Benefits

Other Benefits

Other Benefits

Other Benefits

Other Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Qualified Pension Benefits

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Total

Total

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Total

Total

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Total

Total

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Total

Total

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Total

Total

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Total

Total

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Total

Total

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Total

Total

Level 3

Level 3

Level 3

Level 1

Level 1

Level 2

Level 2

Total

Total

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Total

Total

Level 1

Level 1

Level 2

Level 2

Total

Total

Total

Total

Total

Total

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

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Target Allocation, Minimum

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25.00%

0.00%

10.00%

15.00%

0.00%

5.00%

0.00%

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Target Allocation

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31.00%

9.00%

25.00%

25.00%

0.00%

10.00%

0.00%

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Target Allocation, Maximum

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40.00%

15.00%

30.00%

30.00%

10.00%

15.00%

5.00%

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Fair Value of Plan Assets

$615,721

$531,183

$479,786

$8,774

$7,541

$7,206

$0

$0

$0

'

'

'

'

'

'

'

$62,278

$55,614

$45,319

$615,721

$531,183

$8,703

$7,472

$71

$69

$8,774

$7,541

$431,936

$364,914

$121,721

$110,638

$62,278

$55,615

$615,935

$531,167

$296,929

$244,975

$114,667

$78,194

$0

$0

$411,596

$323,169

$157,874

[1]

$136,994

[1]

$35,851

[1]

$28,890

[1]

$0

[1]

$0

[1]

$193,725

[1]

$165,884

[1]

$62,867

[2]

$51,264

[2]

$0

[2]

$0

[2]

$0

[2]

$0

[2]

$62,867

[2]

$51,264

[2]

$76,188

[3]

$56,717

[3]

$78,816

[3]

$49,304

[3]

$0

[3]

$0

[3]

$155,004

[3]

$106,021

[3]

$0

[4]

$0

[4]

$0

[4]

$26,425

[4]

$0

[4]

$0

[4]

$0

[4]

$26,425

[4]

$135,007

[5]

$119,939

[5]

$0

[5]

$0

[5]

$0

[5]

$0

[5]

$135,007

[5]

$119,939

[5]

$0

[6]

$0

[6]

$0

[6]

$0

[6]

$62,278

[6]

$55,615

[6]

$62,278

[6]

$55,615

[6]

$0

$0

$0

$8,703

[7]

$7,472

[7]

$0

[7]

$0

[7]

$8,703

[7]

$7,472

[7]

$0

[8]

$0

[8]

$7,054

[8]

$6,019

[8]

$0

[8]

$0

[8]

$7,054

[8]

$6,019

[8]

$0

[9]

$0

[9]

$71

[9]

$69

[9]

$71

[9]

$69

[9]

($417)

($173)

$203

$189

[1]

Domestic large cap equity investments are comprised of (1) common stock, and a (2) commingled fund. Investments in common stock are valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013. The investment in the commingled fund is valued at the net asset value per share multiplied by the number of shares held as of December 31, 2013.

[2]

Domestic small cap equity investments are comprised of (1) common stock and a (2) mutual fund. The investments in common stock are valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013. The investment in the mutual fund is valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013.

[3]

Non – US Equity investments are comprised of a (1) mutual fund; and a (2) commingled fund. The investment in the mutual fund is valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013. The investment in the commingled fund is valued at the net asset value per share multiplied by the number of shares held as of December 31, 2013.

[4]

The tactical asset allocation investment is comprised of a commingled fund, which is valued at the net asset value per share multiplied by the number of shares held as of the measurement date.

[5]

Fixed income securities consist of a mutual fund. The investment in the mutual fund is valued using quoted market prices multiplied by the number of shares owned as of December 31, 2013.

[6]

As of December 31, 2013 absolute return investments consist of two partnerships. The partnerships are valued using the financial reports as of December 31, 2013. These investments are a Level 3 under ASC 820 because the significant valuation inputs are primarily internal to the partnerships with little third party involvement.

[7]

This is a publicly traded balanced mutual fund. The fund seeks regular income, conservation of principal, and an opportunity for long-term growth of principal and income. The fair value is determined by taking the number of shares owned by the plan, and multiplying by the market price as of December 31, 2013.

[8]

The investment consists of a money market fund, which is valued at the net asset value per share of $1.00 per unit as of December 31, 2013. The money market fund invests primarily in commercial paper, notes, repurchase agreements, and other evidences of indebtedness which are payable on demand or short-term in nature.

[9]

This is a money market fund. The money market fund investments are valued at the net asset value per share of $1.00 per unit as of December 31, 2013. The money market fund invests primarily in commercial paper, notes, repurchase agreements, and other evidences of indebtedness which are payable on demand or short-term in nature.

Retirement_Benefits_Fair_Value

Retirement Benefits - Fair Value Level 3 Rollforward (Details) (Qualified Pension Benefits, USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified				Fair Value, Measurements, Recurring		Fair Value, Measurements, Recurring		Fair Value, Measurements, Recurring		Fair Value, Measurements, Recurring		Fair Value, Measurements, Recurring		Fair Value, Measurements, Recurring
				Level 3		Level 3		Partnership		Partnership		Mutual Funds		Mutual Funds
								Level 3		Level 3		Level 3		Level 3
Change in plan assets:	'	'	'	'		'		'		'		'		'
Fair value of plan assets at beginning of period	$615,721	$531,183	$479,786	$55,614		$45,319		$55,614		$45,319		$0		$0
Additional investments	'	'	'	0		7,021		0		7,021		0		0
Distributions	'	'	'	0		0		0		0		0		0
Realized losses on distributions	'	'	'	0		0		0		0		0		0
Unrealized gains relating to instruments still held at the reporting date	'	'	'	6,664		3,274		6,664		3,274		0		0
Transferred out of level 3	'	'	'	0	[1]	0	[1]	0	[1]	0	[1]	0	[1]	0	[1]
Fair value of plan assets at end of period	$615,721	$531,183	$479,786	$62,278		$55,614		$62,278		$55,614		$0		$0
[1]	The plan had no transfers between level 2 and level 1 during the years ended December 31, 2013 or 2012.

Retirement_Benefits_Textuals_D

Retirement Benefits - Textuals (Details) (USD $)	12 Months Ended			3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Mar. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013
	Qualified Pension Benefits	SERP Pension Benefits	Other Benefits	PUGET SOUND ENERGY, INC.	PUGET SOUND ENERGY, INC.	PUGET SOUND ENERGY, INC.	PUGET SOUND ENERGY, INC.	PUGET SOUND ENERGY, INC.	Cash Balance Formula	Final Average Earnings Formula
						Qualified Pension Benefits	SERP Pension Benefits	Other Benefits	PUGET SOUND ENERGY, INC.	PUGET SOUND ENERGY, INC.
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'	'	'	'	'	'	'
Defined Contribution Plan, Employer Matching Contribution, Percent	'	'	'	1.00%	4.00%	'	'	'	100.00%	55.00%
Amounts that Will be Amortized from Accumulated Other Comprehensive Income (Loss) in Next Fiscal Year, Net Gain (Loss)	'	($0.90)	'	'	'	($13)	($1.50)	$0.60	'	'
Pension and Other Postretirement Benefit Plans, Net Prior Service Cost or Credit, Amounts that Will be Amortized from Accumulated Other Comprehensive Income (Loss) in Next Fiscal Year	2	'	'	'	'	1.6	'	'	'	'
Estimated Future Employer Contributions in Current Fiscal Year	$12	$4	$0.40	'	'	'	'	'	'	'

Income_Taxes_Components_of_Inc

Income Taxes - Components of Income Tax Expense (Benefit) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Current:	'	'	'
Federal	$0	$4,268	$785
State	0	0	-50
Deferred:	'	'	'
Federal	122,559	100,701	32,706
State	-151	-244	319
Total income tax expense	122,408	104,725	33,760
PUGET SOUND ENERGY, INC.	'	'	'
Current:	'	'	'
Federal	0	4,268	653
State	0	0	0
Deferred:	'	'	'
Federal	160,886	145,040	76,369
State	0	0	1,095
Total income tax expense	$160,886	$149,308	$78,117

Income_Taxes_Income_Tax_Reconc

Income Taxes - Income Tax Reconciliation (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Disclosures [Line Items]	'	'	'
Federal statutory rate	35.00%	'	'
Income Tax Reconciliation [Abstract]	'	'	'
Income taxes at the statutory rate	$142,847	$132,491	$54,968
Production tax credit	-22,414	-22,188	-23,310
AFUDC excluded from taxable income	-9,406	-16,543	-22,861
Capitalized interest	7,294	9,757	17,592
Utility plant differences	9,527	8,674	5,849
Income Tax Reconciliation, Treasury Grant	-7,651	-1,007	0
Tenaska gas contract	1	-4,687	7,094
Other - net	2,210	-1,772	-5,572
Total income tax expense	122,408	104,725	33,760
Effective tax rate	30.00%	27.70%	21.50%
PUGET SOUND ENERGY, INC.	'	'	'
Income Tax Reconciliation [Abstract]	'	'	'
Income taxes at the statutory rate	180,955	176,917	98,783
Production tax credit	-22,414	-22,188	-23,310
AFUDC excluded from taxable income	-9,406	-16,543	-22,861
Capitalized interest	7,294	9,757	17,592
Utility plant differences	9,527	8,674	5,849
Income Tax Reconciliation, Treasury Grant	-7,651	-1,007	0
Tenaska gas contract	1	-4,687	7,094
Other - net	2,580	-1,615	-5,030
Total income tax expense	$160,886	$149,308	$78,117
Effective tax rate	31.10%	29.50%	27.70%

Income_Taxes_Deferred_Income_T

Income Taxes - Deferred Income Taxes (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Deferred Tax Liabilities, Gross	'	'
Utility plant and equipment	$1,625,107	$1,409,216
Regulatory asset for income taxes	146,867	119,844
Fair value of debt instruments	76,991	86,831
Other deferred tax liabilities	202,189	151,820
Subtotal deferred tax liabilities	2,051,154	1,767,711
Deferred Tax Assets, Gross	'	'
Net operating loss carryforward	-374,606	-298,440
Production tax credit carryforward	-135,531	-113,117
Regulatory liability on production tax credit	-71,880	-59,811
Fair value of derivative instruments	-7,166	-44,835
Other deferred tax assets	-60,970	-43,309
Subtotal deferred tax assets	650,153	559,512
Total	1,401,001	1,208,199
PUGET SOUND ENERGY, INC.	'	'
Deferred Tax Liabilities, Gross	'	'
Utility plant and equipment	1,625,107	1,409,216
Regulatory asset for income taxes	146,350	119,279
Other deferred tax liabilities	131,977	132,304
Subtotal deferred tax liabilities	1,903,434	1,660,799
Deferred Tax Assets, Gross	'	'
Net operating loss carryforward	-173,068	-134,513
Production tax credit carryforward	-135,531	-113,117
Regulatory liability on production tax credit	-71,880	-59,811
Fair value of derivative instruments	-9,988	-46,139
Other deferred tax assets	-69,175	-100,632
Subtotal deferred tax assets	459,642	454,212
Total	$1,443,792	$1,206,587

Income_Taxes_Balance_Sheet_Loc

Income Taxes - Balance Sheet Location (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Income Tax Disclosures [Line Items]	'	'
Current deferred taxes	($86,004)	($53,437)
Non-current deferred taxes	1,487,005	1,261,636
Total	1,401,001	1,208,199
PUGET SOUND ENERGY, INC.	'	'
Income Tax Disclosures [Line Items]	'	'
Current deferred taxes	-141,058	-68,015
Non-current deferred taxes	1,584,850	1,274,602
Total	$1,443,792	$1,206,587

Litigation_Details

Litigation (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Mar. 06, 2013	Mar. 06, 2013	Mar. 06, 2013	Mar. 06, 2013	Mar. 06, 2013
		Pending Litigation	Pending Litigation	Colstrip Unit One and Two	Colstrip Unit Three and Four	Sierra Club and Montana Environmental Information Center [Member]	Sierra Club and Montana Environmental Information Center [Member]	Sierra Club and Montana Environmental Information Center [Member]	Sierra Club and Montana Environmental Information Center [Member]	Sierra Club and Montana Environmental Information Center [Member]
						Pending Litigation	Failure to Update Title V Permit	Major Modifications to Title V Permit	Title V compliance certifications incomplete	Opacity
							Pending Litigation	Pending Litigation	Pending Litigation	Pending Litigation
							claim	claim	claim	claim
Loss Contingencies [Line Items]	'	'	'	'	'	'	'	'	'	'
Residential Exchange Program Repayment	$57,000,000	'	'	'	'	'	'	'	'	'
Equity Method Investment, Ownership Percentage	'	'	'	50.00%	25.00%	'	'	'	'	'
Loss Contingency, Pending Claims, Number	'	'	'	'	'	'	1	36	1	1
Loss Contingency, Damages Sought, Value	'	'	'	'	'	100,000	'	'	'	'
Litigation claims accrual	'	$1,400,000	$3,400,000	'	'	'	'	'	'	'

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
	MW			MWh	MWh
	MWh
	Contracts
Long-term Purchase Commitment [Line Items]	'		'	'	'
Percentage of Company's energy output (percent)	15.10%		'	'	'
Average cost of Company's energy output (US$ per kWh)	0.018		'	'	'
Number of Public Utility Districts with long term purchase agreements	3		'	'	'
Contract expenses	$63,365,000		$70,188,000	$81,828,000	'
Megawatt Capacity	750		'	'	'
Estimated 2014 Costs	79,988,000		'	'	'
2014 Debt Service Costs	33,100,000		'	'	'
Interest included in 2014 Debt Service Costs	15,201,000		'	'	'
Debt Outstanding	279,732,000		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	138,299,000		'	'	'
2015	202,436,000		'	'	'
2016	238,458,000		'	'	'
2017	268,213,000		'	'	'
2018	253,882,000		'	'	'
Thereafter	2,082,032,000		'	'	'
Total	3,183,320,000		'	'	'
Total energy obtained during period under purchased power contracts (MWh)	10,700,000		'	6,100,000	8,500,000
Cost incurred during period to provide energy under purchased power contracts	348,700,000		'	203,100,000	391,800,000
Daily take obligation under long-term service contract (percent)	100.00%		'	'	'
Daily delivery obligation under long-term service contract (percent)	100.00%		'	'	'
Columbia River projects	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	67,094,000		'	'	'
2015	69,401,000		'	'	'
2016	70,924,000		'	'	'
2017	71,091,000		'	'	'
2018	62,477,000		'	'	'
Thereafter	601,448,000		'	'	'
Total	942,435,000		'	'	'
Other utilities	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	17,277,000		'	'	'
2015	16,718,000		'	'	'
2016	17,229,000		'	'	'
2017	10,174,000		'	'	'
2018	0		'	'	'
Thereafter	0		'	'	'
Total	61,398,000		'	'	'
Non-utility contracts	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	53,928,000		'	'	'
2015	116,317,000		'	'	'
2016	150,305,000		'	'	'
2017	186,948,000		'	'	'
2018	191,405,000		'	'	'
Thereafter	1,480,584,000		'	'	'
Total	2,179,487,000		'	'	'
Gas-fired generation facility	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	118,600,000		'	'	'
Purchase obligation under longer term (2013 through 2029) agreements	318,100,000		'	'	'
Short-term energy supply contracts	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	32,500,000		'	'	'
2015	10,800,000		'	'	'
2016	2,700,000		'	'	'
Firm transportation service	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	168,936,000		'	'	'
2015	166,452,000		'	'	'
2016	159,899,000		'	'	'
2017	156,205,000		'	'	'
2018	133,281,000		'	'	'
Thereafter	487,739,000		'	'	'
Total	1,272,512,000		'	'	'
Deman charges incurred under firm supply and service contracts	160,800,000		'	'	'
Firm storage service	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	6,528,000		'	'	'
2015	5,337,000		'	'	'
2016	5,209,000		'	'	'
2017	5,209,000		'	'	'
2018	1,407,000		'	'	'
Thereafter	2,793,000		'	'	'
Total	26,483,000		'	'	'
Deman charges incurred under firm supply and service contracts	6,600,000		'	'	'
Firm natural gas supply	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	175,464,000		'	'	'
2015	171,789,000		'	'	'
2016	165,108,000		'	'	'
2017	161,414,000		'	'	'
2018	134,688,000		'	'	'
Thereafter	490,532,000		'	'	'
Total	1,298,995,000		'	'	'
Combustion turbines	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
Deman charges incurred under firm supply and service contracts	39,500,000		'	'	'
Energy production service contracts	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	26,714,000	[1]	'	'	'
2015	33,068,000	[1]	'	'	'
2016	15,728,000	[1]	'	'	'
2017	5,658,000	[1]	'	'	'
2018	4,165,000	[1]	'	'	'
Thereafter	27,182,000	[1]	'	'	'
Total	112,515,000	[1]	'	'	'
Automated meter reading system	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	23,443,000	[2]	'	'	'
2015	24,176,000	[2]	'	'	'
2016	13,063,000	[2]	'	'	'
2017	9,558,000	[2]	'	'	'
2018	9,994,000	[2]	'	'	'
Thereafter	80,106,000	[2]	'	'	'
Total	160,340,000	[2]	'	'	'
Service contract obligations	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
2014	50,157,000		'	'	'
2015	57,244,000		'	'	'
2016	28,791,000		'	'	'
2017	15,216,000		'	'	'
2018	14,159,000		'	'	'
Thereafter	107,288,000		'	'	'
Total	272,855,000		'	'	'
Minimum | Combustion turbines	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
Remaining terms under contract	'less than one year		'	'	'
Maximum | Combustion turbines	'		'	'	'
Payment Obligations for Power Purchases	'		'	'	'
Remaining terms under contract	'31 years		'	'	'
Rock Island Project	'		'	'	'
Long-term Purchase Commitment [Line Items]	'		'	'	'
Percent of Output	25.00%		'	'	'
Megawatt Capacity	156		'	'	'
Estimated 2014 Costs	29,182,000		'	'	'
2014 Debt Service Costs	11,288,000		'	'	'
Interest included in 2014 Debt Service Costs	6,412,000		'	'	'
Debt Outstanding	102,522,000		'	'	'
Rocky Reach Project	'		'	'	'
Long-term Purchase Commitment [Line Items]	'		'	'	'
Percent of Output	25.00%		'	'	'
Megawatt Capacity	325		'	'	'
Estimated 2014 Costs	26,484,000		'	'	'
2014 Debt Service Costs	8,787,000		'	'	'
Interest included in 2014 Debt Service Costs	3,563,000		'	'	'
Debt Outstanding	58,055,000		'	'	'
Wells Project	'		'	'	'
Long-term Purchase Commitment [Line Items]	'		'	'	'
Percent of Output	29.90%		'	'	'
Megawatt Capacity	251		'	'	'
Estimated 2014 Costs	16,258,000		'	'	'
2014 Debt Service Costs	8,675,000		'	'	'
Interest included in 2014 Debt Service Costs	2,678,000		'	'	'
Debt Outstanding	71,679,000		'	'	'
Priest Rapids Development	'		'	'	'
Long-term Purchase Commitment [Line Items]	'		'	'	'
Percent of Output	0.80%		'	'	'
Megawatt Capacity	9		'	'	'
Estimated 2014 Costs	4,032,000		'	'	'
2014 Debt Service Costs	2,175,000		'	'	'
Interest included in 2014 Debt Service Costs	1,274,000		'	'	'
Debt Outstanding	23,738,000		'	'	'
Wanapum Development	'		'	'	'
Long-term Purchase Commitment [Line Items]	'		'	'	'
Percent of Output	0.80%		'	'	'
Megawatt Capacity	9		'	'	'
Estimated 2014 Costs	4,032,000		'	'	'
2014 Debt Service Costs	2,175,000		'	'	'
Interest included in 2014 Debt Service Costs	1,274,000		'	'	'
Debt Outstanding	$23,738,000		'	'	'
[1]	Energy production service contracts include operations and maintenance contracts on Mint Farm, Wild Horse, Goldendale, Hopkins Ridge, Frederickson 1, Ferndale and Lower Snake River facilities.
[2]	Automated meter reading system contractual obligation is the service component of the Landis and Gyr contract.

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 10, 2012

Jun. 18, 2012

Feb. 10, 2012

Jun. 03, 2011

Dec. 31, 2013

Dec. 31, 2012

Feb. 28, 2009

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 04, 2013

Dec. 31, 2013

Dec. 31, 2012

Feb. 04, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 10, 2012

Jun. 03, 2011

Jun. 03, 2011

Dec. 31, 2011

Co-manager and Underwriter

Co-manager and Underwriter

Co-manager and Underwriter

Senior Secured Note

Senior Secured Note

Term Loan

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET SOUND ENERGY, INC.

PUGET ENERGY

PUGET ENERGY

PUGET ENERGY

PUGET ENERGY

PUGET ENERGY

PUGET ENERGY

PUGET ENERGY

Contracts

6.000% Senior Secured Note Due 2021

6.000% Senior Secured Note Due 2021

PUGET ENERGY

PUGET ENERGY

Senior secured credit facility

Senior secured credit facility

Senior Secured Note

Senior Secured Note

Term Loan

PUGET ENERGY

Co-manager and Underwriter

6.000% Senior Secured Note Due 2021

Co-manager and Underwriter

Co-manager and Underwriter

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current borrowing capacity of line of credit

'

'

'

$1,000,000,000

'

'

'

'

'

'

'

'

'

$1,000,000,000

'

'

'

$30,000,000

'

'

'

$1,000,000,000

'

'

'

Debt instrument variable rate basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'one-month LIBOR

'

'

'

'

'

'

'

Basis spread on variable rate (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.25%

0.25%

'

'

'

'

'

'

'

Short-term note owed to parent

'

'

'

'

'

'

'

'

'

'

29,598,000

29,598,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Applicable interest rate on credift facility at period end

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.33%

0.50%

'

'

'

'

'

'

'

'

'

Long-term debt

5,462,272,000

'

'

'

'

'

'

500,000,000

500,000,000

1,225,000,000

3,763,272,000

'

'

'

'

'

'

'

1,699,000,000

'

'

'

'

500,000,000

782,000,000

Repayments of long-term debt

309,860,000

1,273,000,000

769,000,000

'

'

'

'

'

'

'

174,860,000

0

285,000,000

'

'

'

'

'

135,000,000

843,000,000

484,000,000

'

484,000,000

'

'

Number of interest rate derivatives held

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notional amount of interest rate swaps

'

'

'

'

'

'

444,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notional amount of swap instrument settled

'

'

'

'

$300,000,000

$67,500,000

$77,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Segment_Information_Details

Segment Information (Details)	12 Months Ended
	Dec. 31, 2013
	segment
Segment Reporting Information [Line Items]	'
Number of operating segments	1
PUGET SOUND ENERGY, INC.	'
Segment Reporting Information [Line Items]	'
Area of service territory (sqmi)	6,000

Accumulated_Other_Comprehensiv2

Accumulated Other Comprehensive Income (Loss) Changes in AOCI, net of tax (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'	'	'
Accumulated other comprehensive income (loss), net of tax	$47,715	($32,829)	'
Interest Rate Swap	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'	'	'
Accumulated other comprehensive income (loss), net of tax	-3,022	-14,599	-40,041
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	2,928	11,577	25,442
Other Comprehensive Income (Loss), Net of Tax	2,928	11,577	25,442
Accumulated other comprehensive income (loss), net of tax	-94	-3,022	-14,599
Accumulated Defined Benefit Plans Adjustment	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'	'	'
Accumulated other comprehensive income (loss), net of tax	-29,065	-15,195	39,630
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	76,004	-13,574	-53,742
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	1,575	-296	-1,083
Other Comprehensive Income (Loss), Net of Tax	77,579	-13,870	-54,825
Accumulated other comprehensive income (loss), net of tax	48,514	-29,065	-15,195
Derivative	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'	'	'
Accumulated other comprehensive income (loss), net of tax	-742	-1,113	-2,658
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	37	371	1,545
Other Comprehensive Income (Loss), Net of Tax	37	371	1,545
Accumulated other comprehensive income (loss), net of tax	-705	-742	-1,113
Comprehensive Income	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'	'	'
Accumulated other comprehensive income (loss), net of tax	-32,829	-30,907	-3,069
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	76,004	-13,574	-53,742
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	4,540	11,652	25,904
Other Comprehensive Income (Loss), Net of Tax	80,544	-1,922	-27,838
Accumulated other comprehensive income (loss), net of tax	47,715	-32,829	-30,907
PUGET SOUND ENERGY, INC.	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'	'	'
Accumulated other comprehensive income (loss), net of tax	-95,739	-187,198	'
PUGET SOUND ENERGY, INC. | Interest Rate Swap	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'	'	'
Accumulated other comprehensive income (loss), net of tax	-6,624	-6,941	-7,257
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	317	317	316
Other Comprehensive Income (Loss), Net of Tax	317	317	316
Accumulated other comprehensive income (loss), net of tax	-6,307	-6,624	-6,941
PUGET SOUND ENERGY, INC. | Accumulated Defined Benefit Plans Adjustment	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'	'	'
Accumulated other comprehensive income (loss), net of tax	-175,998	-168,704	-115,778
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	74,969	-17,049	-59,468
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	13,624	9,755	6,542
Other Comprehensive Income (Loss), Net of Tax	88,593	-7,294	-52,926
Accumulated other comprehensive income (loss), net of tax	-87,405	-175,998	-168,704
PUGET SOUND ENERGY, INC. | Derivative	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'	'	'
Accumulated other comprehensive income (loss), net of tax	-4,576	-12,934	-34,612
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	2,549	8,358	21,678
Other Comprehensive Income (Loss), Net of Tax	2,549	8,358	21,678
Accumulated other comprehensive income (loss), net of tax	-2,027	-4,576	-12,934
PUGET SOUND ENERGY, INC. | Comprehensive Income	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'	'	'
Accumulated other comprehensive income (loss), net of tax	-187,198	-188,579	-157,647
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	74,969	-17,049	-59,468
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	16,490	18,430	28,536
Other Comprehensive Income (Loss), Net of Tax	91,459	1,381	-30,932
Accumulated other comprehensive income (loss), net of tax	($95,739)	($187,198)	($188,579)

Accumulated_Other_Comprehensiv3

Accumulated Other Comprehensive Income (Loss) Reclassifications Out of Accumulated Other Comprehensive Income (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Comprehensive income (loss)	$366,272		$271,899		$95,452
Interest Rate Contract | Interest Expense	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-4,505		-17,811		-39,143
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	1,577		6,234		13,701
Comprehensive income (loss)	-2,928		-11,577		-25,442
Amortization of Prior Service Cost | Pension Cost	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	1,997	[1]	1,980	[1]	1,980	[1]
Amortization of Net Gain (Loss) | Pension Cost	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-4,420	[1]	-1,524	[1]	-314	[1]
Qualified Pension Benefits | Pension Cost	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-2,423		456		1,666
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	848		-160		-583
Comprehensive income (loss)	-1,575		296		1,083
Electric Derivative | Electric Generation Fuel	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	0		100		-679
Electric Derivative | Purchased Electricity	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-57		-671		-1,698
Electric Derivative | Electric Derivative, Total	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-57		-571		-2,377
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	20		200		832
Comprehensive income (loss)	-37		-371		-1,545
Reclassification out of Accumulated Other Comprehensive Income	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Comprehensive income (loss)	-4,540		-11,652		-25,904
PUGET SOUND ENERGY, INC.	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Comprehensive income (loss)	447,588		357,551		173,188
PUGET SOUND ENERGY, INC. | Interest Rate Contract | Interest Expense	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-488		-488		-488
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	171		171		172
Comprehensive income (loss)	-317		-317		-316
PUGET SOUND ENERGY, INC. | Amortization of Prior Service Cost | Pension Cost	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	1,559	[1]	1,245	[1]	949	[1]
PUGET SOUND ENERGY, INC. | Amortization of Net Gain (Loss) | Pension Cost	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-22,519	[1]	-16,203	[1]	-10,963	[1]
PUGET SOUND ENERGY, INC. | Amortization of Transition Obligation | Pension Cost	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	0	[1]	-50	[1]	-50	[1]
PUGET SOUND ENERGY, INC. | Qualified Pension Benefits | Pension Cost	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-20,960		-15,008		-10,064
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	7,336		5,253		3,522
Comprehensive income (loss)	-13,624		-9,755		-6,542
PUGET SOUND ENERGY, INC. | Electric Derivative | Electric Generation Fuel	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	0		97		-20,625
PUGET SOUND ENERGY, INC. | Electric Derivative | Purchased Electricity	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-3,922		-12,955		-12,726
PUGET SOUND ENERGY, INC. | Electric Derivative | Electric Derivative, Total	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-3,922		-12,858		-33,351
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	1,373		4,500		11,673
Comprehensive income (loss)	-2,549		-8,358		-21,678
PUGET SOUND ENERGY, INC. | Reclassification out of Accumulated Other Comprehensive Income	'		'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'		'
Comprehensive income (loss)	($16,490)		($18,430)		($28,536)
[1]	These accumulated other comprehensive income components are included in the computation of net periodic pension cost (see Note 12 for additional details).

SUPPLEMENTAL_QUARTERLY_FINANCI2

SUPPLEMENTAL QUARTERLY FINANCIAL DATA (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Quarterly Financial Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating revenues	$946,645	$598,348	$642,486	$999,818	$909,272	$578,755	$678,617	$1,048,512	$3,187,297	$3,215,156	$3,318,765
Operating income	242,301	100,043	95,081	317,735	193,374	153,262	159,876	209,023	755,160	715,535	474,940
Net income (loss)	108,808	8,540	905	167,475	80,957	46,692	57,692	88,480	285,728	273,821	123,290
PUGET SOUND ENERGY, INC.	'	'	'	'	'	'	'	'	'	'	'
Quarterly Financial Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating revenues	946,794	598,348	642,486	999,707	909,519	579,611	678,617	1,048,512	3,187,335	3,216,259	3,319,803
Operating income	237,808	96,085	91,094	310,587	188,431	150,007	153,306	201,245	735,574	692,989	431,043
Net income (loss)	$122,923	$26,605	$26,663	$179,938	$95,714	$66,868	$80,872	$112,716	$356,129	$356,170	$204,120

SCHEDULE_I_CONDENSED_FINANCIAL1

SCHEDULE I CONDENSED FINANCIAL INFORMATION OF PUGET ENERGY - Condensed Statements of Income (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Non-utility expense and other	'	'	'	'	'	'	'	'	$3,555	($814)	($9,442)
Unhedged interest rate swap expense	'	'	'	'	'	'	'	'	2,420	-4,288	-28,601
Interest expense	'	'	'	'	'	'	'	'	-392,264	-392,216	-371,910
Income taxes	'	'	'	'	'	'	'	'	-122,408	-104,725	-33,760
Net income (loss)	108,808	8,540	905	167,475	80,957	46,692	57,692	88,480	285,728	273,821	123,290
Comprehensive income (loss)	'	'	'	'	'	'	'	'	366,272	271,899	95,452
PUGET ENERGY	'	'	'	'	'	'	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Non-utility expense and other	'	'	'	'	'	'	'	'	-1,255	-2,040	-2,280
Equity In Net Income (Loss) Of Subsidiaries	'	'	'	'	'	'	'	'	351,718	365,590	228,288
Unhedged interest rate swap expense	'	'	'	'	'	'	'	'	2,420	-4,288	-28,601
Interest income	'	'	'	'	'	'	'	'	114	214	215
Interest expense	'	'	'	'	'	'	'	'	-103,372	-135,312	-131,702
Income taxes	'	'	'	'	'	'	'	'	36,103	49,657	57,370
Net income (loss)	'	'	'	'	'	'	'	'	285,728	273,821	123,290
Comprehensive income (loss)	'	'	'	'	'	'	'	'	$366,272	$271,899	$95,452

SCHEDULE_I_CONDENSED_FINANCIAL2

SCHEDULE I CONDENSED FINANCIAL INFORMATION OF PUGET ENERGY - Condensed Balance Sheets (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011	Dec. 31, 2010
In Thousands, unless otherwise specified
Other property and investments:	'		'		'	'
Goodwill	$1,656,513		$1,656,513		'	'
Current assets:	'		'		'	'
Cash and Cash Equivalents, at Carrying Value	44,302		135,542		37,235	36,557
Deferred income taxes	86,004		53,437		'	'
Total current assets	1,007,190		965,845		'	'
Long-term assets:	'		'		'	'
Other	130,909		95,763		'	'
Total assets	12,906,575		12,835,275		'	'
Capitalization and liabilities:	'		'		'	'
Common equity	3,679,679		3,484,228		3,300,923	3,322,912
Long-term debt	1,699,000		1,834,000		'	'
Total capitalization	8,912,155		8,817,428		'	'
Current liabilities:	'		'		'	'
Accounts payable	296,681		321,960		'	'
Interest	79,303		82,262		'	'
Deferred income taxes	1,487,005		1,261,636		'	'
Unrealized loss on derivative instruments	48,049		177,519		'	'
Total current liabilities	804,293		1,018,885		'	'
Long-term liabilities:	'		'		'	'
Unrealized loss on derivative instruments	38,162		83,276		'	'
Total capitalization and liabilities	12,906,575		12,835,275		'	'
PUGET ENERGY	'		'		'	'
Assets:	'		'		'	'
Investments in subsidiaries	3,508,460		3,490,206		'	'
Other property and investments:	'		'		'	'
Goodwill	1,656,513		1,656,513		'	'
Current assets:	'		'		'	'
Cash and Cash Equivalents, at Carrying Value	191		12		6,224	237
Receivables from affiliates	29,605	[1]	29,608	[1]	'	'
Deferred income taxes	0		2,300		'	'
Total current assets	29,796		31,920		'	'
Long-term assets:	'		'		'	'
Deferred income taxes	241,787		166,896		'	'
Other	17,992		20,944		'	'
Total long-term assets	259,779		187,840		'	'
Total assets	5,454,548		5,366,479		'	'
Capitalization and liabilities:	'		'		'	'
Common equity	3,679,679		3,484,228		'	'
Long-term debt	1,698,964		1,833,959		'	'
Total capitalization	5,378,643		5,318,187		'	'
Current liabilities:	'		'		'	'
Accounts payable	322		212		'	'
Interest	24,047		26,466		'	'
Deferred income taxes	38,296		0		'	'
Unrealized loss on derivative instruments	6,584		6,571		'	'
Total current liabilities	69,249		33,249		'	'
Long-term liabilities:	'		'		'	'
Unrealized loss on derivative instruments	6,656		15,043		'	'
Total long-term liabilities	6,656		15,043		'	'
Total capitalization and liabilities	$5,454,548		$5,366,479		'	'
[1]	Eliminated in consolidation.

SCHEDULE_I_CONDENSED_FINANCIAL3

SCHEDULE I CONDENSED FINANCIAL INFORMATION OF PUGET ENERGY - Condensed Statements of Cash Flows (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating activities:	'	'	'
Net income	$285,728	$273,821	$123,290
Adjustments to reconcile net income to net cash provided by (used in) operating activities:	'	'	'
Unrealized gain on derivative instruments	-106,540	-146,680	45,043
Deferred income taxes and tax credits - net	122,409	100,457	31,774
Taxes	4,499	6,174	65,213
Accounts payable	4,597	-25,963	1,098
Net cash provided by operating activities	766,068	782,685	915,923
Investing activities:	'	'	'
Other	-17,871	-38,923	-7,184
Net cash used in investing activities	-480,918	-692,970	-982,410
Financing activities:	'	'	'
Dividends paid	-170,821	-88,594	-117,441
Long-term notes and bonds issued	161,860	1,314,000	1,382,000
Redemption of term-loan and other long-term debt	-309,860	-1,273,000	-769,000
Net cash provided by (used in) financing activities	-376,390	8,592	67,165
Net increase (decrease) in cash and cash equivalents	-91,240	98,307	678
Cash and cash equivalents at beginning of period	135,542	37,235	36,557
Cash and cash equivalents at end of period	44,302	135,542	37,235
PUGET ENERGY	'	'	'
Operating activities:	'	'	'
Net income	285,728	273,821	123,290
Adjustments to reconcile net income to net cash provided by (used in) operating activities:	'	'	'
Unrealized gain on derivative instruments	-3,869	-12,984	33,549
Deferred income taxes and tax credits - net	-35,872	-49,496	-57,151
Equity in earnings of subsidiary	-351,718	-365,590	-228,288
Other	3,055	11,409	12,837
Dividends received from subsidiaries	410,977	175,625	212,875
Accounts receivable	3	283	618
Taxes	0	0	14,069
Accounts payable	110	212	0
Accrued interest	-1,299	33,842	25,273
Net cash provided by operating activities	307,115	67,122	137,072
Investing activities:	'	'	'
Investment in subsidiaries	0	0	-287,000
(Increase) decrease in loan to subsidiaries	0	400	-7,400
Other	-1,120	-20,901	-16,228
Net cash used in investing activities	-1,120	-20,501	-310,628
Financing activities:	'	'	'
Dividends paid	-170,821	-88,594	-117,441
Long-term notes and bonds issued	0	884,000	787,000
Redemption of term-loan and other long-term debt	-135,000	-843,000	-484,000
Issue costs and others	5	-5,239	-6,016
Net cash provided by (used in) financing activities	-305,816	-52,833	179,543
Net increase (decrease) in cash and cash equivalents	179	-6,212	5,987
Cash and cash equivalents at beginning of period	12	6,224	237
Cash and cash equivalents at end of period	$191	$12	$6,224

SCHEDULE_I_CONDENSED_FINANCIAL4

SCHEDULE I CONDENSED FINANCIAL INFORMATION OF PUGET ENERGY Notes (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net income	$108,808,000	$8,540,000	$905,000	$167,475,000	$80,957,000	$46,692,000	$57,692,000	$88,480,000	$285,728,000	$273,821,000	$123,290,000
Goodwill, Purchase Accounting Adjustments	'	'	'	'	'	'	'	'	-4,400,000	9,400,000	24,200,000
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	'	'	'	'	'	'	'	'	366,272,000	271,899,000	95,452,000
Net Cash Provided by (Used in) Operating Activities	'	'	'	'	'	'	'	'	766,068,000	782,685,000	915,923,000
Net Cash Provided by (Used in) Investing Activities	'	'	'	'	'	'	'	'	-480,918,000	-692,970,000	-982,410,000
Parent Company [Member]	'	'	'	'	'	'	'	'	'	'	'
Net income	'	'	'	'	'	'	'	'	285,728,000	273,821,000	123,290,000
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	'	'	'	'	'	'	'	'	366,272,000	271,899,000	95,452,000
Net Cash Provided by (Used in) Operating Activities	'	'	'	'	'	'	'	'	307,115,000	67,122,000	137,072,000
Net Cash Provided by (Used in) Investing Activities	'	'	'	'	'	'	'	'	-1,120,000	-20,501,000	-310,628,000
PUGET SOUND ENERGY, INC.	'	'	'	'	'	'	'	'	'	'	'
Net income	122,923,000	26,605,000	26,663,000	179,938,000	95,714,000	66,868,000	80,872,000	112,716,000	356,129,000	356,170,000	204,120,000
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	'	'	'	'	'	'	'	'	447,588,000	357,551,000	173,188,000
Net Cash Provided by (Used in) Operating Activities	'	'	'	'	'	'	'	'	835,679,000	797,882,000	809,017,000
Net Cash Provided by (Used in) Investing Activities	'	'	'	'	'	'	'	'	-479,798,000	-672,069,000	-966,183,000
Scenario, Previously Reported	'	'	'	'	'	'	'	'	'	'	'
Net Cash Provided by (Used in) Operating Activities	'	'	'	'	'	'	'	'	'	888,691,000	1,010,328,000
Net Cash Provided by (Used in) Investing Activities	'	'	'	'	'	'	'	'	'	-798,976,000	-1,076,815,000
Scenario, Previously Reported | Parent Company [Member]	'	'	'	'	'	'	'	'	'	'	'
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	'	'	'	'	'	'	'	'	'	285,398,000	148,733,000
Net Cash Provided by (Used in) Operating Activities	'	'	'	'	'	'	'	'	'	46,221,000	120,844,000
Net Cash Provided by (Used in) Investing Activities	'	'	'	'	'	'	'	'	'	400,000	-294,400,000
Scenario, Previously Reported | PUGET SOUND ENERGY, INC.	'	'	'	'	'	'	'	'	'	'	'
Net Cash Provided by (Used in) Operating Activities	'	'	'	'	'	'	'	'	'	903,888,000	903,422,000
Net Cash Provided by (Used in) Investing Activities	'	'	'	'	'	'	'	'	'	($778,075,000)	($1,060,588,000)

SCHEDULE_II_VALUATION_AND_QUAL1

SCHEDULE II VALUATION AND QUALIFYING ACCOUNTS AND RESERVES (Details) (Allowance for doubtful accounts receivable, USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Movement in Valuation Allowances and Reserves [Roll Forward]	'	'	'
Balance At Beginning of Period	$9,932	$8,495	$9,784
Additions Charged to Costs and Expenses	26,330	21,567	18,449
Deductions	28,877	20,130	19,738
Balance At End Of Period	7,385	9,932	8,495
PUGET SOUND ENERGY, INC.	'	'	'
Movement in Valuation Allowances and Reserves [Roll Forward]	'	'	'
Balance At Beginning of Period	9,932	8,495	9,784
Additions Charged to Costs and Expenses	26,330	21,567	18,449
Deductions	28,877	20,130	19,738
Balance At End Of Period	$7,385	$9,932	$8,495