Puget Energy (PSD) 10-Q 2 May 14 2014 Q1 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	3 Months Ended
	Mar. 31, 2014
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 Common Stock, Shares Outstanding	200
Document Fiscal Year Focus	'2014
Document Fiscal Period Focus	'Q1
Document Type	'10-Q
Amendment Flag	'false
Document Period End Date	31-Mar-14
Subsidiaries [Member]	'
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 Common Stock, Shares Outstanding	85,903,791
Document Fiscal Year Focus	'2014
Document Type	'10-Q
Amendment Flag	'false
Document Period End Date	31-Mar-14

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Operating revenue:	'	'
Electric	$633,553	$614,634
Gas	387,443	384,765
Other	4,379	419
Total operating revenue	1,025,375	999,818
Energy costs:	'	'
Purchased electricity	181,157	175,043
Electric generation fuel	75,436	59,087
Residential exchange	-30,003	-22,551
Purchased gas	191,306	189,983
Unrealized (gain) loss on derivative instruments, net	-7,839	-75,692
Utility operations and maintenance	144,076	129,235
Non-utility expense and other	3,422	-994
Depreciation	91,184	88,178
Amortization	10,535	5,744
Conservation amortization	28,982	34,107
Taxes other than income taxes	100,818	99,943
Total operating expenses	789,074	682,083
Operating income	236,301	317,735
Other income (deductions):	'	'
Other income	4,242	12,012
Other expense	-1,582	-1,542
Non-hedged interest rate derivative expense	-747	1,028
Interest charges:	'	'
AFUDC	1,153	4,648
Interest expense	-90,255	-95,816
Income (loss) before income taxes	149,112	238,065
Income tax (benefit) expense	41,520	70,590
Net income (loss)	107,592	167,475
Subsidiaries [Member]	'	'
Operating revenue:	'	'
Electric	633,553	614,634
Gas	387,443	384,765
Other	4,379	308
Total operating revenue	1,025,375	999,707
Energy costs:	'	'
Purchased electricity	181,157	175,043
Electric generation fuel	75,436	59,087
Residential exchange	-30,003	-22,551
Purchased gas	191,306	189,983
Unrealized (gain) loss on derivative instruments, net	-7,270	-72,740
Utility operations and maintenance	144,076	129,235
Non-utility expense and other	6,177	3,091
Depreciation	91,184	88,178
Amortization	10,535	5,744
Conservation amortization	28,982	34,107
Taxes other than income taxes	100,818	99,943
Total operating expenses	792,398	689,120
Operating income	232,977	310,587
Other income (deductions):	'	'
Other income	4,240	12,012
Other expense	-1,582	-1,542
Interest charges:	'	'
AFUDC	1,153	4,648
Interest expense	-64,137	-65,977
Interest expense on parent note	-26	-29
Income (loss) before income taxes	172,625	259,699
Income tax (benefit) expense	51,542	79,761
Net income (loss)	$121,083	$179,938

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Parent [Line Items]	'	'
Net income (loss)	$107,592	$167,475
Other comprehensive income (loss):	'	'
Net unrealized gain (loss) from pension and postretirement plans, net of tax	-209	347
Other Comprehensive Income (Loss), Reclassification Adjustment on Derivatives Included in Net Income, Net of Tax	347	-107
Amortization Of Financing Cash Flow Hedge Contracts To Earnings During Period Net Of Tax	94	854
Other comprehensive income (loss)	232	1,094
Comprehensive income (loss)	107,824	168,569
Subsidiaries [Member]	'	'
Parent [Line Items]	'	'
Net income (loss)	121,083	179,938
Other comprehensive income (loss):	'	'
Net unrealized gain (loss) from pension and postretirement plans, net of tax	2,001	3,386
Other Comprehensive Income (Loss), Reclassification Adjustment on Derivatives Included in Net Income, Net of Tax	718	1,811
Amortization Of Financing Cash Flow Hedge Contracts To Earnings During Period Net Of Tax	79	79
Other comprehensive income (loss)	2,798	5,276
Comprehensive income (loss)	$123,881	$185,214

CONSOLIDATED_STATEMENTS_OF_COM1

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Reclassification of net unrealized loss on interest rate swaps during the period, net of tax	$50	$460
Net unrealized gain (loss) from pension and postretirement plans, tax	113	-186
Reclassification of net unrealized loss on energy derivative instruments during the period, net of tax	-187	57
Subsidiaries [Member]	'	'
Reclassification of net unrealized loss on interest rate swaps during the period, net of tax	1,078	1,823
Net unrealized gain (loss) from pension and postretirement plans, tax	-386	-975
Reclassification of net unrealized loss on energy derivative instruments during the period, net of tax	($43)	($43)

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Utility plant (at original cost, including construction work in progress):	'	'
Electric plant	$7,079,136	$7,019,853
Gas plant	2,557,017	2,528,629
Common plant	457,071	504,036
Less: Accumulated depreciation and amortization	-1,401,652	-1,373,178
Net utility plant	8,691,572	8,679,340
Other property and investments:	'	'
Goodwill	1,656,513	1,656,513
Other property and investments	101,572	100,332
Total other property and investments	1,758,085	1,756,845
Current assets:	'	'
Cash and cash equivalents	23,581	44,302
Restricted cash	25,437	7,171
Accounts receivable, net of allowance for doubtful accounts	432,641	408,512
Unbilled revenue	167,105	219,884
Materials and supplies, at average cost	87,926	88,140
Fuel and gas inventory, at average cost	31,245	66,717
Unrealized gain on derivative instruments	44,889	18,867
Income taxes	149	297
Prepaid expense and other	18,232	18,787
Power contract acquisition adjustment gain	48,243	48,509
Deferred income taxes	77,343	86,004
Total current assets	956,791	1,007,190
Other long-term and regulatory assets:	'	'
Regulatory asset for deferred income taxes	144,166	146,867
Regulatory assets related to power contracts	32,985	33,753
Other regulatory assets	709,094	749,382
Unrealized gain on derivative instruments	6,820	7,733
Power contract acquisition adjustment gain	380,204	394,556
Other	134,186	130,909
Total other long-term and regulatory assets	1,407,455	1,463,200
Total assets	12,813,903	12,906,575
Capitalization:	'	'
Common stock	0	0
Additional paid-in capital	3,308,957	3,308,957
Earnings reinvested in the business	388,518	323,007
Accumulated Other Comprehensive Income (Loss), Net of Tax	47,947	47,715
Total common shareholder's equity	3,745,422	3,679,679
Long-term debt:	'	'
First mortgage bonds and senior notes	3,351,412	3,351,412
Pollution control bonds	161,860	161,860
Junior subordinated notes	250,000	250,000
Long-term debt	1,699,000	1,699,000
Debt discount	-227,013	-229,796
Total long-term debt	5,235,259	5,232,476
Total capitalization	8,980,681	8,912,155
Current liabilities:	'	'
Accounts payable	288,420	296,681
Short-term debt	0	162,000
Purchased gas adjustment liability	2,859	5,938
Accrued expenses:	'	'
Taxes	121,035	109,559
Salaries and wages	28,245	38,491
Interest	74,173	79,303
Unrealized loss on derivative instruments	33,213	48,049
Power contract acquisition adjustment loss	3,889	3,937
Other	84,199	60,335
Total current liabilities	636,033	804,293
Long-term and regulatory liabilities:	'	'
Deferred income taxes	1,517,287	1,487,005
Unrealized loss on derivative instruments	27,444	38,162
Power Cost Adjustment Mechanism	5,394	5,345
Regulatory liabilities	676,750	689,060
Regulatory liabilities related to power contracts	428,447	443,065
Power contract acquisition adjustment loss	29,095	29,816
Other deferred credits	512,772	497,674
Total long-term and regulatory liabilities	3,197,189	3,190,127
Commitments and contingencies	'	'
Total capitalization and liabilities	12,813,903	12,906,575
Subsidiaries [Member]	'	'
Utility plant (at original cost, including construction work in progress):	'	'
Electric plant	9,331,849	9,276,400
Gas plant	3,162,703	3,134,880
Common plant	498,184	565,072
Less: Accumulated depreciation and amortization	-4,301,164	-4,297,012
Net utility plant	8,691,572	8,679,340
Other property and investments:	'	'
Other property and investments	93,159	91,919
Total other property and investments	93,159	91,919
Current assets:	'	'
Cash and cash equivalents	23,556	44,111
Restricted cash	25,437	7,171
Accounts receivable, net of allowance for doubtful accounts	432,915	408,827
Unbilled revenue	167,105	219,884
Materials and supplies, at average cost	87,926	88,140
Fuel and gas inventory, at average cost	28,463	63,914
Unrealized gain on derivative instruments	44,889	18,867
Income taxes	149	297
Prepaid expense and other	18,232	18,770
Deferred income taxes	132,248	141,058
Total current assets	960,920	1,011,039
Other long-term and regulatory assets:	'	'
Regulatory asset for deferred income taxes	143,628	146,350
Other regulatory assets	709,094	749,382
Unrealized gain on derivative instruments	6,820	7,733
Other	127,202	123,125
Total other long-term and regulatory assets	986,744	1,026,590
Total assets	10,732,395	10,808,888
Capitalization:	'	'
Common stock	859	859
Additional paid-in capital	3,246,205	3,246,205
Earnings reinvested in the business	336,401	289,432
Accumulated Other Comprehensive Income (Loss), Net of Tax	-92,941	-95,739
Total common shareholder's equity	3,490,524	3,440,757
Long-term debt:	'	'
First mortgage bonds and senior notes	3,351,412	3,351,412
Pollution control bonds	161,860	161,860
Junior subordinated notes	250,000	250,000
Debt discount	-14	-14
Total long-term debt	3,763,258	3,763,258
Total capitalization	7,253,782	7,204,015
Current liabilities:	'	'
Accounts payable	288,415	296,675
Short-term debt	0	162,000
Short-term note owed to parent	29,598	29,598
Purchased gas adjustment liability	2,859	5,938
Accrued expenses:	'	'
Taxes	121,035	109,559
Salaries and wages	28,245	38,491
Interest	57,094	55,262
Unrealized loss on derivative instruments	26,461	41,465
Other	84,199	60,334
Total current liabilities	637,906	799,322
Long-term and regulatory liabilities:	'	'
Deferred income taxes	1,626,368	1,584,850
Unrealized loss on derivative instruments	22,070	31,523
Power Cost Adjustment Mechanism	5,394	5,345
Regulatory liabilities	674,103	686,176
Other deferred credits	512,772	497,657
Total long-term and regulatory liabilities	2,840,707	2,805,551
Commitments and contingencies	'	'
Total capitalization and liabilities	$10,732,395	$10,808,888

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified
ASSETS	'	'
Construction work in progress	$299,952	$310,318
Current assets:	'	'
Allowance for doubtful accounts	8,551	7,385
Common shareholderbs 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
Subsidiaries [Member]	'	'
ASSETS	'	'
Construction work in progress	299,952	310,318
Current assets:	'	'
Allowance for doubtful accounts	$8,551	$7,385
Common shareholderbs 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
Common stock, shares outstanding (in shares)	85,903,791	85,903,791

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Operating activities:	'	'
Net income (loss)	$107,592	$167,475
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation	91,184	88,178
Amortization	10,535	5,744
Conservation amortization	28,982	34,107
Deferred income taxes and tax credits, net	41,520	70,591
Net unrealized (gain) loss on derivative instruments	-8,793	-75,937
Derivative contracts classified as financing activities due to merger	8,026	26,049
AFUDC - Equity	-1,436	-6,524
Funding of pension liability	-3,000	-5,100
Regulatory Assets	-38,240	-28,953
Regulatory liabilities	6,407	3,029
Other long-term assets	-5,667	3,099
Other long-term liabilities	21,532	17,586
Change in certain current assets and liabilities:	'	'
Accounts receivable and unbilled revenue	28,650	31,548
Materials and supplies	214	1,827
Fuel and gas inventory	35,451	27,097
Income taxes	148	148
Prepayments and other	539	-3,732
Purchased gas adjustment	-3,079	-5,718
Accounts payable	-13,886	-47,935
Taxes payable	11,476	16,746
Accrued expenses and other	-7,621	-18,060
Net cash provided by operating activities	310,534	301,265
Investing activities:	'	'
Construction expenditures - excluding equity AFUDC	-96,318	-168,337
Proceeds from disposition of assets	0	108,166
Restricted cash	-18,266	599
Other	-4,125	-4,248
Net cash used in investing activities	-118,709	-63,820
Financing activities:	'	'
Change in short-term debt and leases, net	-163,903	-157,895
Dividends paid	-42,081	-42,071
Redemption of bonds and notes	0	-29,000
Derivative contracts classified as financing activities due to merger	-8,026	-26,049
Issuance cost of bonds and other	1,464	-3,984
Net cash provided by (used in) financing activities	-212,546	-258,999
Net increase (decrease) in cash and cash equivalents	-20,721	-21,554
Cash and cash equivalents at beginning of period	44,302	135,542
Cash and cash equivalents at end of period	23,581	113,988
Supplemental cash flow information:	'	'
Cash payments for interest (net of capitalized interest)	90,756	78,346
Subsidiaries [Member]	'	'
Operating activities:	'	'
Net income (loss)	121,083	179,938
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation	91,184	88,178
Amortization	10,535	5,744
Conservation amortization	28,982	34,107
Deferred income taxes and tax credits, net	51,543	79,761
Net unrealized (gain) loss on derivative instruments	-7,270	-72,740
AFUDC - Equity	-1,436	-6,524
Funding of pension liability	-3,000	-5,100
Regulatory Assets	-38,240	-28,953
Regulatory liabilities	6,407	3,029
Other long-term assets	-3,251	2,922
Other long-term liabilities	19,275	18,162
Change in certain current assets and liabilities:	'	'
Accounts receivable and unbilled revenue	28,691	31,313
Materials and supplies	214	1,827
Fuel and gas inventory	35,451	27,097
Income taxes	148	148
Prepayments and other	539	-3,732
Purchased gas adjustment	-3,079	-5,718
Accounts payable	-13,886	-47,721
Taxes payable	11,476	16,746
Accrued expenses and other	-1,276	-8,783
Net cash provided by operating activities	334,090	309,701
Investing activities:	'	'
Construction expenditures - excluding equity AFUDC	-96,318	-168,337
Proceeds from disposition of assets	0	108,166
Restricted cash	-18,266	599
Other	-3,507	-4,184
Net cash used in investing activities	-118,091	-63,756
Financing activities:	'	'
Change in short-term debt and leases, net	-163,903	-157,895
Dividends paid	-74,114	-105,648
Issuance cost of bonds and other	1,463	-3,985
Net cash provided by (used in) financing activities	-236,554	-267,528
Net increase (decrease) in cash and cash equivalents	-20,555	-21,583
Cash and cash equivalents at beginning of period	44,111	135,530
Cash and cash equivalents at end of period	23,556	113,947
Supplemental cash flow information:	'	'
Cash payments for interest (net of capitalized interest)	$59,666	$57,646

Summary_of_Significant_Account

Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Summary of Significant Accounting Policies	'
	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 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 which have been revised are summarized below:
		As Reported			As Revised
	Puget Energy	Three Months Ended			Three Months Ended
	(Dollars in Thousands)	31-Mar-13			31-Mar-13
	Operating Activities:
	Regulatory Assets	$	(6,411	)	$	(28,953	)
	Net Cash Provided by Operating Activities	$	323,807		$	301,265
	Investing Activities:
	Energy Efficiency Expenditures	$	(22,542	)	$	—
	Net Cash Used in Investing Activities	$	(86,362	)	$	(63,820	)
		As Reported			As Revised
	Puget Sound Energy	Three Months Ended			Three Months Ended
	(Dollars in Thousands)	31-Mar-13			31-Mar-13
	Operating Activities:
	Regulatory Assets	$	(6,411	)	$	(28,953	)
	Net Cash Provided by Operating Activities	$	332,243		$	309,701
	Investing Activities:
	Energy Efficiency Expenditures	$	(22,542	)	$	—
	Net Cash Used in Investing Activities	$	(86,298	)	$	(63,756	)

Accounting_for_Derivative_Inst

Accounting for Derivative Instruments and Hedging Activities	3 Months Ended
	Mar. 31, 2014
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 strategy objective is to minimize 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 agreements are variable. 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 March 31, 2014, 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	March 31, 2014							December 31, 2013
	Puget Sound Energy
	(Dollars in Thousands)	Volumes	Assets 1			Liabilities 2			Volumes	Assets 1			Liabilities 2
	Interest rate swap derivatives 3	$450 million	$	—		$	12,126		$450 million	$	—		$	13,223
	Electric portfolio derivatives	*	23,906			34,365			*	18,479			37,312
	Natural gas derivatives (MMBtus) 4	380.5 million	27,803			14,166			423.5 million	8,121			35,676
	Total derivative contracts		$	51,709		$	60,657			$	26,600		$	86,211
	Current		$	44,889		$	33,213			$	18,867		$	48,049
	Long-term		6,820			27,444				7,733			38,162
	Total derivative contracts		$	51,709		$	60,657			$	26,600		$	86,211
	___________
	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	All fair value adjustments on derivatives relating to the natural gas business have been deferred in accordance with ASC 980, “Regulated Operations” (ASC 980) due to the PGA mechanism. The net derivative asset or liability and offsetting regulatory liability or asset are related to contracts used to economically hedge the cost of physical gas purchased to serve natural gas customers.
	*	Electric portfolio derivatives consist of electric generation fuel of 129.3 million One Million British Thermal Units (MMBtus) and purchased electricity of 7.6 million Megawatt Hours (MWhs) at March 31, 2014, and 145.6 million MMBtus and 8.6 million MWhs at December 31, 2013.
	For further details regarding the fair value of derivative instruments, see Note 3.
	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
	March 31, 2014
		Gross Amount 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
	(Dollars in Thousands)										Commodity Contracts			Cash Collateral Received/Posted		Net Amount
	Assets
	Energy Derivative Contracts	$	51,709		$	—		$	51,709		$	(26,319	)	$	—	$	25,390
	Liabilities
	Energy Derivative Contracts	$	48,531		$	—		$	48,531		$	(26,319	)	$	—	$	22,212
	Interest Rate Swaps 2	$	12,126		$	—		$	12,126		$	—		$	—	$	12,126
	Puget Energy and Puget Sound Energy
	December 31, 2013
		Gross Amount 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
	(Dollars in Thousands)										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
	___________
	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 Normal Purchase Normal Sale (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		Three Months Ended March 31,
	(Dollars in Thousands)	Location	2014			2013
	Interest rate contracts:	Non-hedged interest rate swap	$	(747	)	$	1,028
		(expense) income
		Interest expense	(125		)	(2,578		)
	Commodity contracts:
	Electric derivatives	Unrealized gain (loss) on derivative instruments, net	7,839			75,692
		Electric generation fuel	7,827			(12,638		)
		Purchased electricity	5,383			(31,485		)
	Total gain (loss) recognized in income on derivatives		$	20,177		$	30,019
	Puget Sound Energy		Three Months Ended March 31,
	(Dollars in Thousands)	Location	2014			2013
	Commodity contracts:
	Electric derivatives	Unrealized gain (loss) on derivative instruments, net	$	7,270		$	72,740
		Electric generation fuel	7,827			(12,638		)
		Purchased electricity	5,383			(31,485		)
	Total gain (loss) recognized in income on derivatives		$	20,480		$	28,617
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 three months ended March 31, 2014 and 2013, cash outflows related to financing activities of $8.0 million and $26.0 million, respectively, were reported on the Puget Energy statement of cash flows.
For derivative instruments previously designated as cash flow hedges (including both commodity contracts and interest rate swaps), the effective portion of the gain or loss on the derivative was recorded as a component of Other Comprehensive Income (OCI), and then is reclassified into earnings in the same period(s) during which the hedged transaction affects earnings.
Puget Energy and PSE expect $0.5 million and $2.0 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) of derivatives that were previously in a cash flow hedge relationship, and subsequently reclassified out of accumulated OCI into income:
Puget Energy		Three Months Ended March 31,
(Dollars in Thousands)	Location	2014			2013
Interest rate contracts:	Interest expense	$	(144	)	$	(1,314	)
Commodity contracts:
Electric derivatives	Electric generation fuel	—			—
	Purchased electricity	(534		)	164
Total		$	(678	)	$	(1,150	)
Puget Sound Energy		Three Months Ended March 31,
(Dollars in Thousands)	Location	2014			2013
Interest rate contracts:	Interest expense	$	(122	)	$	(122	)
Commodity contracts:
Electric derivatives	Electric generation fuel	—			—
	Purchased electricity	(1,104		)	(2,786		)
Total		$	(1,226	)	$	(2,908	)
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 March 31, 2014, 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 booked as contra accounts to unrealized gain (loss) positions. As of March 31, 2014, the Company was in a net liability position with many of its counterparties, so the default factors of counterparties did not have a significant impact on reserves for the period. The majority of the Company's derivative contracts are with financial institutions and other utilities operating within the Western Electricity Coordinating Council. As of March 31, 2014, 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 March 31, 2014:
Puget Energy and Puget Sound Energy	Fair Value 1			Posted			Contingent
Contingent Feature
(Dollars in Thousands)	Liability			Collateral			Collateral
Credit rating 2	$	(10,290	)	$	—		$	10,290
Requested credit for adequate assurance	(10,596		)	—			—
Forward value of contract 3	(1,931		)	—			—
Total	$	(22,817	)	$	—		$	10,290
__________
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	3 Months Ended
	Mar. 31, 2014
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 market 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 London Interbank Offered Rate (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 fair value hierarchy by level, the carrying value for cash, cash equivalents, restricted cash, notes receivable and short-term debt. The carrying values below are representative of fair values due to the short-term nature of these financial instruments.
		Carrying / Fair Value									Carrying / Fair Value
	Puget Energy	At March 31, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	23,581		$	—		$	23,581		$	44,302		$	—		$	44,302
	Restricted Cash	25,437			—			25,437			7,171			—			7,171
	Notes Receivable and Other	—			54,542			54,542			—			53,449			53,449
	Total assets	$	49,018		$	54,542		$	103,560		$	51,473		$	53,449		$	104,922
	Liabilities:
	Short-term debt	$	—		$	—		$	—		$	162,000		$	—		$	162,000
	Total liabilities	$	—		$	—		$	—		$	162,000		$	—		$	162,000
		Carrying / Fair Value									Carrying / Fair Value
	Puget Sound Energy	At March 31, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	23,556		$	—		$	23,556		$	44,111		$	—		$	44,111
	Restricted Cash	25,437			—			25,437			7,171			—			7,171
	Notes Receivable and Other	—			54,542			54,542			—			53,449			53,449
	Total assets	$	48,993		$	54,542		$	103,535		$	51,282		$	53,449		$	104,731
	Liabilities:
	Short-term debt	$	—		$	—		$	—		$	162,000		$	—		$	162,000
	Short-term debt owed to parent	—			29,598			29,598			—			29,598			29,598
	Total liabilities	$	—		$	29,598		$	29,598		$	162,000		$	29,598		$	191,598
	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		March 31, 2014						December 31, 2013
	(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value
	Liabilities:
	Junior subordinated notes	2	$	250,000		$	280,137		$	250,000		$	269,366
	Long-term debt (fixed-rate), net of discount	2	4,686,259			5,875,347			4,683,476			5,594,314
	Long-term debt (variable-rate)	2	299,000			299,000			299,000			299,000
	Total		$	5,235,259		$	6,454,484		$	5,232,476		$	6,162,680
	Puget Sound Energy		March 31, 2014						December 31, 2013
	(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value
	Liabilities:
	Junior subordinated notes	2	$	250,000		$	280,137		$	250,000		$	269,366
	Long-term debt (fixed-rate), net of discount	2	3,513,258			4,239,741			3,513,258			4,038,455
	Total		$	3,763,258		$	4,519,878		$	3,763,258		$	4,307,821
	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:
	Puget Energy	Fair Value									Fair Value
		At March 31, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
	Interest rate derivative instruments	$	12,126		$	—		$	12,126		$	13,223		$	—		$	13,223
	Total derivative liabilities	$	12,126		$	—		$	12,126		$	13,223		$	—		$	13,223
	Puget Energy and	Fair Value									Fair Value
	Puget Sound Energy	At March 31, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
	Assets:
	Electric derivative instruments	$	18,866		$	5,040		$	23,906		$	14,661		$	3,818		$	18,479
	Natural gas derivative instruments	25,253			2,550			27,803			5,448			2,673			8,121
	Total assets	$	44,119		$	7,590		$	51,709		$	20,109		$	6,491		$	26,600
	Liabilities:
Electric derivative instruments	$	14,719		$	19,646		$	34,365		$	18,073		$	19,239		$	37,312
Natural gas derivative instruments	10,513			3,653			14,166			32,642			3,034			35,676
Total liabilities	$	25,232		$	23,299		$	48,531		$	50,715		$	22,273		$	72,988
The following table presents the Company's reconciliation of the changes in the fair value of Level 3 derivatives in the fair value hierarchy:
Puget Energy and	Three Months Ended March 31,
Puget Sound Energy
Level 3 Roll-Forward Net Asset/(Liability)	2014									2013
(Dollars in Thousands)	Electric			Gas			Total			Electric			Gas			Total
Balance at beginning of period	$	(15,421	)	$	(361	)	$	(15,782	)	$	(33,924	)	$	(1,602	)	$	(35,526	)
Changes during period:
Realized and unrealized energy derivatives:
Included in earnings 1	(2,745		)	—			(2,745		)	1,598			—			1,598
Included in regulatory assets / liabilities	—			259			259			—			674			674
Settlements 2	321			(410		)	(89		)	6,384			(733		)	5,651
Transferred into Level 3	3,100			(585		)	2,515			(7,700		)	—			(7,700		)
Transferred out of Level 3	139			(6		)	133			7,200			127			7,327
Balance at end of period	$	(14,606	)	$	(1,103	)	$	(15,709	)	$	(26,442	)	$	(1,534	)	$	(27,976	)
_________
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 $(9.2) million and $1.4 million for the three months ended March 31, 2014 and 2013, 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 reported periods. 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 March 31, 2014:
(Dollars in Thousands)
	Fair Value								Range
Derivative Instrument	Assets 1			Liabilities 1			Valuation Technique	Unobservable Input	Low	High	Weighted Average
Electric	$	5,040		$	19,646		Discounted cash flow	Power Prices	$4.38 per MWh	$49.95 per MWh	$35.67 per MWh
Natural gas	$	2,550		$	3,653		Discounted cash flow	Natural Gas Prices	$3.62 per MMBtu	$4.63 per MMBtu	$4.04 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 March 31, 2014, 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 $12.1 million.

Retirement_Benefits

Retirement Benefits	3 Months Ended
	Mar. 31, 2014
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. Participation by continuing employees in the Cash Balance pension plan is not affected.
	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 re-measurement of the retirement plans are recorded at Puget Energy.
	The following tables summarize the Company’s net periodic benefit cost for the three months ended March 31, 2014 and 2013:
	Puget Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
		Three Months Ended March 31,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:
	Service cost	$	4,512		$	4,709		$	261		$	375		$	29		$	34
	Interest cost	7,055			6,194			577			511			183			176
	Expected return on plan assets	(10,721		)	(9,851		)	—			—			(133		)	(108		)
	Amortization of prior service	(495		)	(495		)	11			(4		)	—			—
	cost
	Amortization of net loss	—			650			228			365			(66		)	17
	(gain)
	Net periodic benefit cost	$	351		$	1,207		$	1,077		$	1,247		$	13		$	119
	Puget Sound Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
		Three Months Ended March 31,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:
	Service cost	$	4,512		$	4,709		$	261		$	375		$	29		$	34
	Interest cost	7,055			6,194			577			511			183			176
	Expected return on plan assets	(10,919		)	(10,249		)	—			—			(133		)	(108		)
	Amortization of prior service	(393		)	(393		)	11			(4		)	1			8
	cost
	Amortization of net loss	3,239			5,085			365			548			(143		)	(34		)
	(gain)
	Net periodic benefit cost	$	3,494		$	5,346		$	1,214		$	1,430		$	(63	)	$	76
	The following table summarizes the Company’s change in benefit obligation for the periods ended March 31, 2014 and December 31, 2013:
	Puget Energy and	Qualified						SERP						Other
	Puget Sound Energy	Pension Benefits						Pension Benefits						Benefits
		Three Months Ended			Year			Three Months Ended			Year			Three Months Ended			Year
					Ended						Ended						Ended
	(Dollars in Thousands)	March 31,			December 31,			March 31,			December 31,			March 31,			December 31,
		2014			2013			2014			2013			2014			2013
	Change in benefit obligation:
	Benefit obligation at beginning of period	$	573,317		$	616,290		$	47,279		$	51,795		$	14,939		$	17,672
	Service cost	4,512			19,285			261			1,498			29			134
	Interest cost	7,055			24,754			577			2,045			183			664
	Amendment	—			—			—			478			—			—
	Actuarial loss/(gain)	—			(48,559		)	—			(1,687		)	—			(2,240		)
	Benefits paid	(10,001		)	(38,453		)	(460		)	(6,850		)	(391		)	(1,536		)
	Medicare part D subsidiary	—			—			—			—			42			245
	received
	Benefit obligation at end of period	$	574,883		$	573,317		$	47,657		$	47,279		$	14,802		$	14,939
	The aggregate expected contributions by the Company to fund the qualified pension 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. During the three months ended March 31, 2014, the Company contributed $3.0 million, $0.5 million, and $0.2 million to fund the qualified pension plan, SERP and the other postretirement plan, respectively.

Regulation_and_Rates

Regulation and Rates	3 Months Ended
	Mar. 31, 2014
Regulation and Rates [Abstract]	'
Regulation and Rates	'
	Regulation and Rates
	On January 31, 2013, the Washington Commission approved a rate change to 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 will pass through eleven months of amortization for both grants to eligible customers beginning February 1, 2013, including grant amortization pass-back of $34.6 million and interest pass-back of $23.8 million. This represents an overall average rate decrease of 2.76%.
	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 is an increase for electric of $21.4 million, or 1.0% annually, and an increase for natural gas of $10.8 million, or 1.1% annually. The allowed decoupling revenue per customer for the recovery of delivery system costs will subsequently increase by 3.0% for the electric customers and 2.2% for the gas customers on January 1 of each year, until the conclusion of PSE's next general rate case.
	The estimated revenue impact of the ERF filings is an increase for electric of $30.7 million, or 1.5% annually, while the revenue impact for natural gas is a decrease of $2.0 million, or a decrease of 0.2% annually. The ERF filings also provided for the collection of property taxes through a property tax tracker mechanism. The property tax rate tracker will initially produce no incremental revenue, but is intended to reduce regulatory lag associated with the recovery of future increases in property tax expenses. PSE's 2012 and 2013 property taxes that are not in current rates will be recovered in later years. 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. 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 reviews 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 9, 2014.
	On October 23, 2013, the Washington Commission approved an update on the Company's power cost only rate case (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.
	On October 30, 2013, the Washington Commission approved PSE's PGA natural gas tariff, effective 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.
	On October 30, 2013, the Washington Commission approved PSE's Pipeline Replacement Program Plan (PRPP) that would accelerate and enhance the safety of the natural gas system and ultimately reduce costs. Under the PRPP plan, PSE would be allowed to file a tariff revision to recover its costs associated with the acceleration of the replacement of natural gas pipelines with the Washington Commission.
	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% as compared to the previous rate.
	On April 24, 2014, the Washington Commission approved PSE’s request to change rates under its electric and natural gas decoupling mechanism, effective May 1, 2014.  The rate change incorporated the effects of an increase to the allowed delivery revenue per customer as well as true-ups to the rate from the prior year.  This represents a rate increase for electric of $10.6 million, or 0.5% annually, and a rate decrease for natural gas of $1.0 million, or 0.1% annually.
	On April 24, 2014, the Washington Commission also approved PSE’s request to change rates under its electric and natural gas property tax tracker mechanism, effective May 1, 2014.  The rate change incorporated the effects of an increase in the amount of property taxes paid as well as true-ups to the rate from the prior year.  This represents a rate increase for electric of $11.0 million, or 0.5% annually, and a rate increase for natural gas of $5.6 million, or 0.6% annually.

Litigation

Litigation	3 Months Ended
	Mar. 31, 2014
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 Bonneville Power Administration (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. Subsequent to the order lifting the stay, in February 2014, one group of petitioners in the other pending Ninth Circuit litigation moved to dismiss its petition and its motion was granted. Two of the remaining petitioners may seek dismissal of their petitions, but other remaining petitioners have not submitted such a motion but rather have stated to the Ninth Circuit that they are pursuing certain claims. PSE is unable to determine 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 $62.9 million in 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.
	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 thirty-six 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 the case has been bifurcated into separate liability and remedy trials. The liability trial is currently set for June 2015, and a date for the remedy trial has yet to be determined. 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 $1.36 million and $1.38 million relating to these claims as of March 31, 2014 and December 31, 2013, respectively.

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Income (Notes)	3 Months Ended
	Mar. 31, 2014
Equity [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 three months ended March 31, 2014:
	Puget 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 interest rate swaps
	Changes in AOCI, net of tax
	(Dollars in Thousands)										Total
	Balance at December 31, 2013	$	48,514		$	(705	)	$	(94	)	$	47,715
	Other comprehensive income (loss) before reclassifications	—			—			—			—
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	(209		)	347			94			232
	Net current-period other comprehensive income (loss)	(209		)	347			94			232
	Balance at March 31, 2014	$	48,305		$	(358	)	$	—		$	47,947
	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, 2013	$	(87,405	)	$	(2,027	)	$	(6,307	)	$	(95,739	)
	Other comprehensive income (loss) before reclassifications	—			—			—			—
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	2,001			718			79			2,798
	Net current-period other comprehensive income (loss)	2,001			718			79			2,798
	Balance at March 31, 2014	$	(85,404	)	$	(1,309	)	$	(6,228	)	$	(92,941	)
	Details about these reclassifications out of accumulated other comprehensive income (loss) for the three months ended March 31, 2014 and March 31, 2013, respectively, are as follows:
	Puget Energy		Three Months Ended			Three Months Ended
	(Dollars in Thousands)		March 31, 2014			March 31, 2013
	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)
	Net unrealized gain (loss) and prior service cost on pension plans:
	Amortization of prior service cost	(a)	484			499
	Amortization of net gain (loss)	(a)	(162		)	(1,032		)
		Total before tax	322			(533		)
		Tax (expense) or benefit	(113		)	186
		Net of Tax	$	209		$	(347	)
	Net unrealized gain (loss) on energy derivative instruments:
	Commodity contracts: electric derivatives	Purchased electricity	(534		)	164
		Tax (expense) or benefit	187			(57		)
		Net of Tax	$	(347	)	$	107
	Net unrealized gain (loss) on interest rate swaps:
	Interest rate contracts	Interest expense	$	(144	)	$	(1,314	)
		Tax (expense) or benefit	50			460
		Net of Tax	$	(94	)	$	(854	)
	Total reclassification for the period	Net of Tax	$	(232	)	$	(1,094	)
	__________
	(a)	These accumulated other comprehensive income components are included in the computation of net periodic pension cost (see Note 4 for additional details).
	Puget Sound Energy		Three Months Ended			Three Months Ended
	(Dollars in Thousands)		March 31, 2014			March 31, 2013
	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)
	Net unrealized gain (loss) and prior service cost on pension plans:
	Amortization of prior service cost	(a)	$	381		$	389
	Amortization of net gain (loss)	(a)	(3,461		)	(5,599		)
		Total before tax	(3,080		)	(5,210		)
		Tax (expense) or benefit	1,079			1,824
		Net of Tax	$	(2,001	)	$	(3,386	)
	Net unrealized gain (loss) on energy derivative instruments:
	Commodity contracts: electric derivatives	Purchased electricity	(1,104		)	(2,786		)
		Tax (expense) or benefit	386			975
		Net of Tax	$	(718	)	$	(1,811	)
	Net unrealized gain (loss) on treasury interest rate swaps:
	Interest rate contracts	Interest expense	(122		)	(122		)
		Tax (expense) or benefit	43			43
		Net of Tax	$	(79	)	$	(79	)
	Total reclassification for the period	Net of Tax	$	(2,798	)	$	(5,276	)
	__________
	(a)	These accumulated other comprehensive income components are included in the computation of net periodic pension cost (see Note 4 for additional details).

Other

Other	3 Months Ended
	Mar. 31, 2014
Other [Abstract]	'
Other	'
	Other
	Jefferson County Public Utility District (JPUD)
	PSE completed the sale of its electric infrastructure assets located in Jefferson County and the transition of electrical services in the county to 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 forty-eight months. On March 28, 2014, intervenors filed response testimonies containing their respective proposals for allocation of the gain, which included a proposal of up to $57.0 million to customers and $3.0 million to PSE. The Washington Commission will hold evidentiary hearings in this matter beginning May 21, 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.
	Bond Issuances
	On May 23, 2013, PSE refinanced $161.9 million of its Pollution Control Revenue Refunding Bonds (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.
	Credit Facilities
	In April 2014, subsequent to the close of the first quarter, the Company completed a one-year extension on both of the liquidity and hedging facilities of PSE, extending the maturity from February 2018 to April 2019. All other terms and conditions of the facilities remain unchanged from when they were committed in 2013. At this same time, the Company completed a one-year extension on the senior secured credit facility of Puget Energy, extending the maturity from February 2017 to April 2018. There were no significant changes to other terms and conditions.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	'
	Summary of Significant Accounting Policies
	Basis of Presentation
	Puget Energy is an energy services holding company that owns PSE.  PSE is a public utility incorporated in the state of Washington that furnishes electric and natural gas services in a territory covering approximately 6,000 square miles, primarily in the Puget Sound region.  Following the merger with Puget Holdings LLC (Puget Holdings) in 2009, Puget Energy is an indirect wholly-owned subsidiary of Puget Holdings.
	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 intercompany transactions.  PSE’s consolidated financial statements continue to be accounted for on a historical basis and do not include any purchase accounting adjustments.
	The consolidated financial statements contained in this Form 10-Q are unaudited.  In the respective opinions of the management of Puget Energy and PSE, all adjustments necessary for a fair statement of the results for the interim periods have been reflected and were of a normal recurring nature.  These consolidated financial statements should be read in conjunction with the audited financial statements (and the Combined Notes thereto) included in the combined Puget Energy and PSE Annual Report on Form 10-K for the year ended December 31, 2013.
	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.
	PSE collected Washington State excise taxes (which are a component of general retail customer rates) and municipal taxes totaling $77.9 million and $76.9 million for the three months ended March 31, 2014 and 2013, 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 Purchased Gas Adjustment (PGA) rates are excluded from the decoupling mechanism.
	Statements of Cash Flows
	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 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 which have been revised are summarized below:
		As Reported			As Revised
	Puget Energy	Three Months Ended			Three Months Ended
	(Dollars in Thousands)	31-Mar-13			31-Mar-13
	Operating Activities:
	Regulatory Assets	$	(6,411	)	$	(28,953	)
	Net Cash Provided by Operating Activities	$	323,807		$	301,265
	Investing Activities:
	Energy Efficiency Expenditures	$	(22,542	)	$	—
	Net Cash Used in Investing Activities	$	(86,362	)	$	(63,820	)
		As Reported			As Revised
	Puget Sound Energy	Three Months Ended			Three Months Ended
	(Dollars in Thousands)	31-Mar-13			31-Mar-13
	Operating Activities:
	Regulatory Assets	$	(6,411	)	$	(28,953	)
	Net Cash Provided by Operating Activities	$	332,243		$	309,701
	Investing Activities:
	Energy Efficiency Expenditures	$	(22,542	)	$	—
	Net Cash Used in Investing Activities	$	(86,298	)	$	(63,756	)
Basis of Presentation	'
	Summary of Significant Accounting Policies
	Basis of Presentation
	Puget Energy is an energy services holding company that owns PSE.  PSE is a public utility incorporated in the state of Washington that furnishes electric and natural gas services in a territory covering approximately 6,000 square miles, primarily in the Puget Sound region.  Following the merger with Puget Holdings LLC (Puget Holdings) in 2009, Puget Energy is an indirect wholly-owned subsidiary of Puget Holdings.
	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 intercompany transactions.  PSE’s consolidated financial statements continue to be accounted for on a historical basis and do not include any purchase accounting adjustments.
	The consolidated financial statements contained in this Form 10-Q are unaudited.  In the respective opinions of the management of Puget Energy and PSE, all adjustments necessary for a fair statement of the results for the interim periods have been reflected and were of a normal recurring nature.  These consolidated financial statements should be read in conjunction with the audited financial statements (and the Combined Notes thereto) included in the combined Puget Energy and PSE Annual Report on Form 10-K for the year ended December 31, 2013.
	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.
Revenue Recognition	'
	PSE collected Washington State excise taxes (which are a component of general retail customer rates) and municipal taxes totaling $77.9 million and $76.9 million for the three months ended March 31, 2014 and 2013, 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 Purchased Gas Adjustment (PGA) rates are excluded from the decoupling mechanism.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	3 Months Ended
	Mar. 31, 2014
Entity Information [Line Items]	'
Reclassification, Policy [Policy Text Block]	'
	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 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 which have been revised are summarized below:
		As Reported			As Revised
	Puget Energy	Three Months Ended			Three Months Ended
	(Dollars in Thousands)	31-Mar-13			31-Mar-13
	Operating Activities:
	Regulatory Assets	$	(6,411	)	$	(28,953	)
	Net Cash Provided by Operating Activities	$	323,807		$	301,265
	Investing Activities:
	Energy Efficiency Expenditures	$	(22,542	)	$	—
	Net Cash Used in Investing Activities	$	(86,362	)	$	(63,820	)
		As Reported			As Revised
	Puget Sound Energy	Three Months Ended			Three Months Ended
	(Dollars in Thousands)	31-Mar-13			31-Mar-13
	Operating Activities:
	Regulatory Assets	$	(6,411	)	$	(28,953	)
	Net Cash Provided by Operating Activities	$	332,243		$	309,701
	Investing Activities:
	Energy Efficiency Expenditures	$	(22,542	)	$	—
	Net Cash Used in Investing Activities	$	(86,298	)	$	(63,756	)

Accounting_for_Derivative_Inst1

Accounting for Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Mar. 31, 2014
Derivative [Line Items]	'
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	March 31, 2014							December 31, 2013
	Puget Sound Energy
	(Dollars in Thousands)	Volumes	Assets 1			Liabilities 2			Volumes	Assets 1			Liabilities 2
	Interest rate swap derivatives 3	$450 million	$	—		$	12,126		$450 million	$	—		$	13,223
	Electric portfolio derivatives	*	23,906			34,365			*	18,479			37,312
	Natural gas derivatives (MMBtus) 4	380.5 million	27,803			14,166			423.5 million	8,121			35,676
	Total derivative contracts		$	51,709		$	60,657			$	26,600		$	86,211
	Current		$	44,889		$	33,213			$	18,867		$	48,049
	Long-term		6,820			27,444				7,733			38,162
	Total derivative contracts		$	51,709		$	60,657			$	26,600		$	86,211
	___________
	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	All fair value adjustments on derivatives relating to the natural gas business have been deferred in accordance with ASC 980, “Regulated Operations” (ASC 980) due to the PGA mechanism. The net derivative asset or liability and offsetting regulatory liability or asset are related to contracts used to economically hedge the cost of physical gas purchased to serve natural gas customers.
	*	Electric portfolio derivatives consist of electric generation fuel of 129.3 million One Million British Thermal Units (MMBtus) and purchased electricity of 7.6 million Megawatt Hours (MWhs) at March 31, 2014, and 145.6 million MMBtus and 8.6 million MWhs at December 31, 2013.
Offsetting Assets and Liabilities	'
	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
	March 31, 2014
		Gross Amount 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
	(Dollars in Thousands)										Commodity Contracts			Cash Collateral Received/Posted		Net Amount
	Assets
	Energy Derivative Contracts	$	51,709		$	—		$	51,709		$	(26,319	)	$	—	$	25,390
	Liabilities
	Energy Derivative Contracts	$	48,531		$	—		$	48,531		$	(26,319	)	$	—	$	22,212
	Interest Rate Swaps 2	$	12,126		$	—		$	12,126		$	—		$	—	$	12,126
	Puget Energy and Puget Sound Energy
	December 31, 2013
		Gross Amount 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
	(Dollars in Thousands)										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
	___________
	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 Credit Risk Related Contingent Features	'
	The table below presents the fair value of the overall contractual contingent liability positions for the Company's derivative activity at March 31, 2014:
	Puget Energy and Puget Sound Energy	Fair Value 1			Posted			Contingent
	Contingent Feature
	(Dollars in Thousands)	Liability			Collateral			Collateral
	Credit rating 2	$	(10,290	)	$	—		$	10,290
	Requested credit for adequate assurance	(10,596		)	—			—
	Forward value of contract 3	(1,931		)	—			—
	Total	$	(22,817	)	$	—		$	10,290
	__________
	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.
PUGET ENERGY [Member]	'
Derivative [Line Items]	'
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	'
	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		Three Months Ended March 31,
	(Dollars in Thousands)	Location	2014			2013
	Interest rate contracts:	Non-hedged interest rate swap	$	(747	)	$	1,028
		(expense) income
		Interest expense	(125		)	(2,578		)
	Commodity contracts:
	Electric derivatives	Unrealized gain (loss) on derivative instruments, net	7,839			75,692
		Electric generation fuel	7,827			(12,638		)
		Purchased electricity	5,383			(31,485		)
	Total gain (loss) recognized in income on derivatives		$	20,177		$	30,019
Subsidiaries [Member]	'
Derivative [Line Items]	'
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	'
	Puget Sound Energy		Three Months Ended March 31,
	(Dollars in Thousands)	Location	2014			2013
	Commodity contracts:
	Electric derivatives	Unrealized gain (loss) on derivative instruments, net	$	7,270		$	72,740
		Electric generation fuel	7,827			(12,638		)
		Purchased electricity	5,383			(31,485		)
	Total gain (loss) recognized in income on derivatives		$	20,480		$	28,617
Schedule of Derivative Instruments, Effect on Other Comprehensive Income (Loss)	'
	Puget Sound Energy		Three Months Ended March 31,
	(Dollars in Thousands)	Location	2014			2013
	Interest rate contracts:	Interest expense	$	(122	)	$	(122	)
	Commodity contracts:
	Electric derivatives	Electric generation fuel	—			—
		Purchased electricity	(1,104		)	(2,786		)
	Total		$	(1,226	)	$	(2,908	)
Parent [Member]	'
Derivative [Line Items]	'
Schedule of Derivative Instruments, Effect on Other Comprehensive Income (Loss)	'
	The following tables present the Company's pre-tax gain (loss) of derivatives that were previously in a cash flow hedge relationship, and subsequently reclassified out of accumulated OCI into income:
	Puget Energy		Three Months Ended March 31,
	(Dollars in Thousands)	Location	2014			2013
	Interest rate contracts:	Interest expense	$	(144	)	$	(1,314	)
	Commodity contracts:
	Electric derivatives	Electric generation fuel	—			—
		Purchased electricity	(534		)	164
	Total		$	(678	)	$	(1,150	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Fair Value, by Balance Sheet Grouping	'
	The following table presents the fair value hierarchy by level, the carrying value for cash, cash equivalents, restricted cash, notes receivable and short-term debt. The carrying values below are representative of fair values due to the short-term nature of these financial instruments.
		Carrying / Fair Value									Carrying / Fair Value
	Puget Energy	At March 31, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	23,581		$	—		$	23,581		$	44,302		$	—		$	44,302
	Restricted Cash	25,437			—			25,437			7,171			—			7,171
	Notes Receivable and Other	—			54,542			54,542			—			53,449			53,449
	Total assets	$	49,018		$	54,542		$	103,560		$	51,473		$	53,449		$	104,922
	Liabilities:
	Short-term debt	$	—		$	—		$	—		$	162,000		$	—		$	162,000
	Total liabilities	$	—		$	—		$	—		$	162,000		$	—		$	162,000
		Carrying / Fair Value									Carrying / Fair Value
	Puget Sound Energy	At March 31, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	23,556		$	—		$	23,556		$	44,111		$	—		$	44,111
	Restricted Cash	25,437			—			25,437			7,171			—			7,171
	Notes Receivable and Other	—			54,542			54,542			—			53,449			53,449
	Total assets	$	48,993		$	54,542		$	103,535		$	51,282		$	53,449		$	104,731
	Liabilities:
	Short-term debt	$	—		$	—		$	—		$	162,000		$	—		$	162,000
	Short-term debt owed to parent	—			29,598			29,598			—			29,598			29,598
	Total liabilities	$	—		$	29,598		$	29,598		$	162,000		$	29,598		$	191,598
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		March 31, 2014						December 31, 2013
	(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value
	Liabilities:
	Junior subordinated notes	2	$	250,000		$	280,137		$	250,000		$	269,366
	Long-term debt (fixed-rate), net of discount	2	4,686,259			5,875,347			4,683,476			5,594,314
	Long-term debt (variable-rate)	2	299,000			299,000			299,000			299,000
	Total		$	5,235,259		$	6,454,484		$	5,232,476		$	6,162,680
	Puget Sound Energy		March 31, 2014						December 31, 2013
	(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value
	Liabilities:
	Junior subordinated notes	2	$	250,000		$	280,137		$	250,000		$	269,366
	Long-term debt (fixed-rate), net of discount	2	3,513,258			4,239,741			3,513,258			4,038,455
	Total		$	3,763,258		$	4,519,878		$	3,763,258		$	4,307,821
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	'
	Puget Energy and	Three Months Ended March 31,
	Puget Sound Energy
	Level 3 Roll-Forward Net Asset/(Liability)	2014									2013
	(Dollars in Thousands)	Electric			Gas			Total			Electric			Gas			Total
	Balance at beginning of period	$	(15,421	)	$	(361	)	$	(15,782	)	$	(33,924	)	$	(1,602	)	$	(35,526	)
	Changes during period:
	Realized and unrealized energy derivatives:
	Included in earnings 1	(2,745		)	—			(2,745		)	1,598			—			1,598
	Included in regulatory assets / liabilities	—			259			259			—			674			674
	Settlements 2	321			(410		)	(89		)	6,384			(733		)	5,651
	Transferred into Level 3	3,100			(585		)	2,515			(7,700		)	—			(7,700		)
	Transferred out of Level 3	139			(6		)	133			7,200			127			7,327
	Balance at end of period	$	(14,606	)	$	(1,103	)	$	(15,709	)	$	(26,442	)	$	(1,534	)	$	(27,976	)
	_________
	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 $(9.2) million and $1.4 million for the three months ended March 31, 2014 and 2013, respectively.
	2	The Company had no purchases, sales or issuances during the reported periods
Fair Value Inputs, Assets and Liabilities, Quantitative Information	'
	Below are the forward price ranges for the Company's purchased commodity contracts, as of March 31, 2014:
	(Dollars in Thousands)
		Fair Value								Range
	Derivative Instrument	Assets 1			Liabilities 1			Valuation Technique	Unobservable Input	Low	High	Weighted Average
	Electric	$	5,040		$	19,646		Discounted cash flow	Power Prices	$4.38 per MWh	$49.95 per MWh	$35.67 per MWh
	Natural gas	$	2,550		$	3,653		Discounted cash flow	Natural Gas Prices	$3.62 per MMBtu	$4.63 per MMBtu	$4.04 per MMBtu
	__________
	1	The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions
PUGET ENERGY [Member]	'
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 Energy	Fair Value									Fair Value
		At March 31, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
	Interest rate derivative instruments	$	12,126		$	—		$	12,126		$	13,223		$	—		$	13,223
	Total derivative liabilities	$	12,126		$	—		$	12,126		$	13,223		$	—		$	13,223
Subsidiaries [Member]	'
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 Energy and	Fair Value									Fair Value
	Puget Sound Energy	At March 31, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
	Assets:
	Electric derivative instruments	$	18,866		$	5,040		$	23,906		$	14,661		$	3,818		$	18,479
	Natural gas derivative instruments	25,253			2,550			27,803			5,448			2,673			8,121
	Total assets	$	44,119		$	7,590		$	51,709		$	20,109		$	6,491		$	26,600
	Liabilities:
	Electric derivative instruments	$	14,719		$	19,646		$	34,365		$	18,073		$	19,239		$	37,312
	Natural gas derivative instruments	10,513			3,653			14,166			32,642			3,034			35,676
	Total liabilities	$	25,232		$	23,299		$	48,531		$	50,715		$	22,273		$	72,988

Retirement_Benefits_Tables

Retirement Benefits (Tables)	3 Months Ended
	Mar. 31, 2014
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Schedule of Changes in Projected Benefit Obligations	'
	The following table summarizes the Company’s change in benefit obligation for the periods ended March 31, 2014 and December 31, 2013:
	Puget Energy and	Qualified						SERP						Other
	Puget Sound Energy	Pension Benefits						Pension Benefits						Benefits
		Three Months Ended			Year			Three Months Ended			Year			Three Months Ended			Year
					Ended						Ended						Ended
	(Dollars in Thousands)	March 31,			December 31,			March 31,			December 31,			March 31,			December 31,
		2014			2013			2014			2013			2014			2013
	Change in benefit obligation:
	Benefit obligation at beginning of period	$	573,317		$	616,290		$	47,279		$	51,795		$	14,939		$	17,672
	Service cost	4,512			19,285			261			1,498			29			134
	Interest cost	7,055			24,754			577			2,045			183			664
	Amendment	—			—			—			478			—			—
	Actuarial loss/(gain)	—			(48,559		)	—			(1,687		)	—			(2,240		)
	Benefits paid	(10,001		)	(38,453		)	(460		)	(6,850		)	(391		)	(1,536		)
	Medicare part D subsidiary	—			—			—			—			42			245
	received
	Benefit obligation at end of period	$	574,883		$	573,317		$	47,657		$	47,279		$	14,802		$	14,939
PUGET ENERGY [Member]	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Schedule of Net Benefit Costs	'
	The following tables summarize the Company’s net periodic benefit cost for the three months ended March 31, 2014 and 2013:
	Puget Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
		Three Months Ended March 31,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:
	Service cost	$	4,512		$	4,709		$	261		$	375		$	29		$	34
	Interest cost	7,055			6,194			577			511			183			176
	Expected return on plan assets	(10,721		)	(9,851		)	—			—			(133		)	(108		)
	Amortization of prior service	(495		)	(495		)	11			(4		)	—			—
	cost
	Amortization of net loss	—			650			228			365			(66		)	17
	(gain)
	Net periodic benefit cost	$	351		$	1,207		$	1,077		$	1,247		$	13		$	119
Subsidiaries [Member]	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Schedule of Net Benefit Costs	'
	Puget Sound Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
		Three Months Ended March 31,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:
	Service cost	$	4,512		$	4,709		$	261		$	375		$	29		$	34
	Interest cost	7,055			6,194			577			511			183			176
	Expected return on plan assets	(10,919		)	(10,249		)	—			—			(133		)	(108		)
	Amortization of prior service	(393		)	(393		)	11			(4		)	1			8
	cost
	Amortization of net loss	3,239			5,085			365			548			(143		)	(34		)
	(gain)
	Net periodic benefit cost	$	3,494		$	5,346		$	1,214		$	1,430		$	(63	)	$	76

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Income (Tables)	3 Months Ended
	Mar. 31, 2014
PUGET ENERGY [Member]	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Schedule of 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 three months ended March 31, 2014:
	Puget 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 interest rate swaps
	Changes in AOCI, net of tax
	(Dollars in Thousands)										Total
	Balance at December 31, 2013	$	48,514		$	(705	)	$	(94	)	$	47,715
	Other comprehensive income (loss) before reclassifications	—			—			—			—
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	(209		)	347			94			232
	Net current-period other comprehensive income (loss)	(209		)	347			94			232
	Balance at March 31, 2014	$	48,305		$	(358	)	$	—		$	47,947
Reclassification out of Accumulated Other Comprehensive Income	'
	Details about these reclassifications out of accumulated other comprehensive income (loss) for the three months ended March 31, 2014 and March 31, 2013, respectively, are as follows:
	Puget Energy		Three Months Ended			Three Months Ended
	(Dollars in Thousands)		March 31, 2014			March 31, 2013
	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)
	Net unrealized gain (loss) and prior service cost on pension plans:
	Amortization of prior service cost	(a)	484			499
	Amortization of net gain (loss)	(a)	(162		)	(1,032		)
		Total before tax	322			(533		)
		Tax (expense) or benefit	(113		)	186
		Net of Tax	$	209		$	(347	)
	Net unrealized gain (loss) on energy derivative instruments:
	Commodity contracts: electric derivatives	Purchased electricity	(534		)	164
		Tax (expense) or benefit	187			(57		)
		Net of Tax	$	(347	)	$	107
	Net unrealized gain (loss) on interest rate swaps:
	Interest rate contracts	Interest expense	$	(144	)	$	(1,314	)
		Tax (expense) or benefit	50			460
		Net of Tax	$	(94	)	$	(854	)
	Total reclassification for the period	Net of Tax	$	(232	)	$	(1,094	)
Subsidiaries [Member]	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Schedule of Accumulated Other Comprehensive Income (Loss)	'
	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, 2013	$	(87,405	)	$	(2,027	)	$	(6,307	)	$	(95,739	)
	Other comprehensive income (loss) before reclassifications	—			—			—			—
	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	2,001			718			79			2,798
	Net current-period other comprehensive income (loss)	2,001			718			79			2,798
	Balance at March 31, 2014	$	(85,404	)	$	(1,309	)	$	(6,228	)	$	(92,941	)
Reclassification out of Accumulated Other Comprehensive Income	'
	Puget Sound Energy		Three Months Ended			Three Months Ended
	(Dollars in Thousands)		March 31, 2014			March 31, 2013
	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)
	Net unrealized gain (loss) and prior service cost on pension plans:
	Amortization of prior service cost	(a)	$	381		$	389
	Amortization of net gain (loss)	(a)	(3,461		)	(5,599		)
		Total before tax	(3,080		)	(5,210		)
		Tax (expense) or benefit	1,079			1,824
		Net of Tax	$	(2,001	)	$	(3,386	)
	Net unrealized gain (loss) on energy derivative instruments:
	Commodity contracts: electric derivatives	Purchased electricity	(1,104		)	(2,786		)
		Tax (expense) or benefit	386			975
		Net of Tax	$	(718	)	$	(1,811	)
	Net unrealized gain (loss) on treasury interest rate swaps:
	Interest rate contracts	Interest expense	(122		)	(122		)
		Tax (expense) or benefit	43			43
		Net of Tax	$	(79	)	$	(79	)
	Total reclassification for the period	Net of Tax	$	(2,798	)	$	(5,276	)
	__________
	(a)	These accumulated other comprehensive income components are included in the computation of net periodic pension cost (see Note 4 for additional details).

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details) (Subsidiaries [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
	sqmi
Subsidiaries [Member]	'	'
Schedule of Capitalization, Equity [Line Items]	'	'
Area of Service Territory (in sqmi)	6,000	'
Excise taxes collected	$77.90	$76.90

Summary_of_Significant_Account4

Summary of Significant Accounting Policies Cash Flow Restatements (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Regulatory Assets	($38,240)	($28,953)
Net Cash Provided by (Used in) Operating Activities	310,534	301,265
Energy Efficiency Expenditures	'	0
Net Cash Provided by (Used in) Investing Activities	-118,709	-63,820
Scenario, Previously Reported [Member]	'	'
Regulatory Assets	'	-6,411
Net Cash Provided by (Used in) Operating Activities	'	323,807
Energy Efficiency Expenditures	'	-22,542
Net Cash Provided by (Used in) Investing Activities	'	-86,362
Subsidiaries [Member]	'	'
Regulatory Assets	-38,240	-28,953
Net Cash Provided by (Used in) Operating Activities	334,090	309,701
Energy Efficiency Expenditures	'	0
Net Cash Provided by (Used in) Investing Activities	-118,091	-63,756
Subsidiaries [Member] | Scenario, Previously Reported [Member]	'	'
Regulatory Assets	'	-6,411
Net Cash Provided by (Used in) Operating Activities	'	332,243
Energy Efficiency Expenditures	'	-22,542
Net Cash Provided by (Used in) Investing Activities	'	($86,298)

Accounting_for_Derivative_Inst2

Accounting for Derivative Instruments and Hedging Activities Derivative Activity and Notional Amounts (Details) (USD $)	Mar. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Interest Rate Swap [Member] | Not Designated as Hedging Instrument [Member]	'		'
Derivative [Line Items]	'		'
Derivative, Notional Amount	$450	[1]	$450	[1]
Natural Gas Derivatives [Member] | Not Designated as Hedging Instrument [Member]	'		'
Derivative [Line Items]	'		'
Derivative, Notional amount, Nonmonetary	380,500,000	[2]	423,500,000	[2]
Electric generation fuel [Member] | Not Designated as Hedging Instrument [Member]	'		'
Derivative [Line Items]	'		'
Derivative, Notional amount, Nonmonetary	129,300,000		145,600,000
Purchased Electricity [Member] | Not Designated as Hedging Instrument [Member]	'		'
Derivative [Line Items]	'		'
Derivative, Notional amount, Nonmonetary	7,600,000		8,600,000
PUGET ENERGY [Member] | Interest Rate Swap [Member]	'		'
Derivative [Line Items]	'		'
Number of Interest Rate Derivatives Held	2		'
[1]	3B Interest rate swap contracts are only held at Puget Energy.
[2]	4B All fair value adjustments on derivatives relating to the natural gas business have been deferred in accordance with ASC 980, bRegulated Operationsb (ASC 980) due to the PGA mechanism. The net derivative asset or liability and offsetting regulatory liability or asset are related to contracts used to economically hedge the cost of physical gas purchased to serve natural gas customers.

Accounting_for_Derivative_Inst3

Accounting for Derivative Instruments and Hedging Activities Derivative Assets and Liabilities (Details) (USD $)	3 Months Ended
	Mar. 31, 2014		Dec. 31, 2013
Derivative [Line Items]	'		'
Document Period End Date	31-Mar-14		'
Unrealized gain on derivative instruments	$44,889,000		$18,867,000
Assets, Long-term	6,820,000		7,733,000
Unrealized loss on derivative instruments	33,213,000		48,049,000
Unrealized loss on derivative instruments	27,444,000		38,162,000
Subsidiaries [Member]	'		'
Derivative [Line Items]	'		'
Document Period End Date	31-Mar-14		'
Unrealized gain on derivative instruments	44,889,000		18,867,000
Assets, Long-term	6,820,000		7,733,000
Unrealized loss on derivative instruments	26,461,000		41,465,000
Unrealized loss on derivative instruments	22,070,000		31,523,000
Commodity Contract [Member]	'		'
Derivative [Line Items]	'		'
Assets	51,709,000		26,600,000
Liabilities	48,531,000		72,988,000
Not Designated as Hedging Instrument [Member]	'		'
Derivative [Line Items]	'		'
Assets	51,709,000	[1]	26,600,000	[1]
Liabilities	60,657,000	[2]	86,211,000	[2]
Not Designated as Hedging Instrument [Member] | PUGET ENERGY [Member]	'		'
Derivative [Line Items]	'		'
Unrealized gain on derivative instruments	44,889,000	[1]	18,867,000	[1]
Assets, Long-term	6,820,000	[1]	7,733,000	[1]
Unrealized loss on derivative instruments	33,213,000	[2]	48,049,000	[2]
Unrealized loss on derivative instruments	27,444,000	[2]	38,162,000	[2]
Not Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]	'		'
Derivative [Line Items]	'		'
Derivative, Notional Amount	450,000,000	[3]	450,000,000	[3]
Assets	0	[1],[3]	0	[1],[3]
Liabilities	12,126,000	[2],[3]	13,223,000	[2],[3]
Not Designated as Hedging Instrument [Member] | Electric portfolio [Member]	'		'
Derivative [Line Items]	'		'
Assets	23,906,000	[1]	18,479,000	[1]
Liabilities	34,365,000	[2]	37,312,000	[2]
Not Designated as Hedging Instrument [Member] | Natural gas portfolio [Member]	'		'
Derivative [Line Items]	'		'
Assets	27,803,000	[1],[4]	8,121,000	[1],[4]
Liabilities	$14,166,000	[2],[4]	$35,676,000	[2],[4]
Not Designated as Hedging Instrument [Member] | Natural Gas Derivatives [Member]	'		'
Derivative [Line Items]	'		'
Derivative, Nonmonetary Notional Amount	380,500,000	[4]	423,500,000	[4]
[1]	1B Balance sheet location: Current and Long-term Unrealized gain on derivative instruments.
[2]	2B Balance sheet location: Current and Long-term Unrealized loss on derivative instruments.
[3]	3B Interest rate swap contracts are only held at Puget Energy.
[4]	4B All fair value adjustments on derivatives relating to the natural gas business have been deferred in accordance with ASC 980, bRegulated Operationsb (ASC 980) due to the PGA mechanism. The net derivative asset or liability and offsetting regulatory liability or asset are related to contracts used to economically hedge the cost of physical gas purchased to serve natural gas customers.

Accounting_for_Derivative_Inst4

Accounting for Derivative Instruments and Hedging Activities Net Amount of Derivatives Reported in the Statement of Financial Position (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014		Dec. 31, 2013		Mar. 31, 2014		Dec. 31, 2013
			Commodity Contract [Member]		Commodity Contract [Member]		Interest Rate Contract [Member]		Interest Rate Contract [Member]
Derivative [Line Items]	'	'	'		'		'		'
Derivative contracts classified as financing activities due to merger	($8,026)	($26,049)	'		'		'		'
Assets	'	'	'		'		'		'
Gross Amount Recognized in the Statement of Financial Position	'	'	51,709	[1]	26,600	[1]	'		'
Gross Amounts Offset in the Statement of Financial Position	'	'	0		0		'		'
Net of Amounts Presented in the Statement of Financial Position	'	'	51,709		26,600		'		'
Commodity Contracts	'	'	-26,319		-19,491		'		'
Cash Collateral Received	'	'	0		0		'		'
Net Amount	'	'	25,390		7,109		'		'
Liabilities	'	'	'		'		'		'
Gross Amount Recognized in the Statement of Financial Position	'	'	48,531	[1]	72,988	[1]	12,126	[1],[2]	13,223	[1],[2]
Gross Amounts Offset in the Statement of Financial Position	'	'	0		0		0	[2]	0	[2]
Net of Amounts Presented in the Statement of Financial Position	'	'	48,531		72,988		12,126	[2]	13,223	[2]
Commodity Contracts	'	'	-26,319		-19,491		0	[2]	0	[2]
Cash Collateral Posted	'	'	0		0		0	[2]	0	[2]
Net Amount	'	'	$22,212		$53,497		$12,126	[2]	$13,223	[2]
[1]	1B All Derivative Contract deals are executed under ISDA, NAESB and WSPP Master Netting Agreements with Right of Offset.
[2]	2B Interest Rate Swap Contracts are only held at Puget Energy.

Accounting_for_Derivative_Inst5

Accounting for Derivative Instruments and Hedging Activities Recognized in Statement of Income (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Document Period End Date	31-Mar-14	'
Purchased electricity	$181,157	$175,043
Unrealized (gain) loss on derivative instruments	-7,839	-75,692
Subsidiaries [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Document Period End Date	31-Mar-14	'
Purchased electricity	181,157	175,043
Unrealized (gain) loss on derivative instruments	-7,270	-72,740
Not Designated as Hedging Instrument [Member] | PUGET ENERGY [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Unrealized (gain) loss on derivative instruments	-20,177	-30,019
Not Designated as Hedging Instrument [Member] | PUGET ENERGY [Member] | Other Income (Deductions) [Member] | Interest Expense [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Unrealized (gain) loss on derivative instruments	747	-1,028
Not Designated as Hedging Instrument [Member] | PUGET ENERGY [Member] | Interest Rate Contract [Member] | Interest Expense [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Unrealized (gain) loss on derivative instruments	125	2,578
Not Designated as Hedging Instrument [Member] | PUGET ENERGY [Member] | Commodity Contract [Member] | Unrealized (Gain) Loss on Derivative Instruments, Net [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Unrealized (gain) loss on derivative instruments	-7,839	-75,692
Not Designated as Hedging Instrument [Member] | PUGET ENERGY [Member] | Commodity Contract [Member] | Electric generation fuel [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Unrealized (gain) loss on derivative instruments	-7,827	12,638
Not Designated as Hedging Instrument [Member] | PUGET ENERGY [Member] | Commodity Contract [Member] | Purchased Electricity [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Unrealized (gain) loss on derivative instruments	-5,383	31,485
Not Designated as Hedging Instrument [Member] | Subsidiaries [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Unrealized (gain) loss on derivative instruments	-20,480	-28,617
Not Designated as Hedging Instrument [Member] | Subsidiaries [Member] | Commodity Contract [Member] | Unrealized (Gain) Loss on Derivative Instruments, Net [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Unrealized (gain) loss on derivative instruments	-7,270	-72,740
Not Designated as Hedging Instrument [Member] | Subsidiaries [Member] | Commodity Contract [Member] | Electric generation fuel [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Unrealized (gain) loss on derivative instruments	-7,827	12,638
Not Designated as Hedging Instrument [Member] | Subsidiaries [Member] | Commodity Contract [Member] | Purchased Electricity [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Unrealized (gain) loss on derivative instruments	-5,383	31,485
Cash Flow Hedging [Member] | PUGET ENERGY [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	-678	-1,150
Cash Flow Hedging [Member] | PUGET ENERGY [Member] | Electric generation fuel [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	0
Cash Flow Hedging [Member] | Subsidiaries [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	-1,226	-2,908
Cash Flow Hedging [Member] | Subsidiaries [Member] | Electric generation fuel [Member]	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	$0	$0

Accounting_for_Derivative_Inst6

Accounting for Derivative Instruments and Hedging Activities Recognized in Other Comprehensive Income (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Document Period End Date	31-Mar-14	'
PUGET ENERGY [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Cash Flow Hedge Loss to be Reclassified within Twelve Months	($500,000)	'
Subsidiaries [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Document Period End Date	31-Mar-14	'
Cash Flow Hedge Loss to be Reclassified within Twelve Months	-2,000,000	'
Cash Flow Hedging [Member] | PUGET ENERGY [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	-678,000	-1,150,000
Cash Flow Hedging [Member] | PUGET ENERGY [Member] | Electric generation fuel [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	0
Cash Flow Hedging [Member] | Subsidiaries [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	-1,226,000	-2,908,000
Cash Flow Hedging [Member] | Subsidiaries [Member] | Electric generation fuel [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	$0	$0

Accounting_for_Derivative_Inst7

Accounting for Derivative Instruments and Hedging Activities Contractual Contingent Liability (Details) (USD $)	Mar. 31, 2014
In Thousands, unless otherwise specified
Electric portfolio [Member]	'
Derivative [Line Items]	'
Fair Value Liability	($22,817)	[1]
Posted Collateral	0
Additional Collateral, Aggregate Fair Value	10,290
Electric portfolio [Member] | Credit rating [Member]	'
Derivative [Line Items]	'
Fair Value Liability	-10,290	[1],[2]
Posted Collateral	0	[2]
Additional Collateral, Aggregate Fair Value	10,290	[2]
Electric portfolio [Member] | Requested credit for adequate assurance [Member]	'
Derivative [Line Items]	'
Fair Value Liability	-10,596	[1]
Posted Collateral	0
Additional Collateral, Aggregate Fair Value	0
Electric portfolio [Member] | Forward value of contract [Member]	'
Derivative [Line Items]	'
Fair Value Liability	-1,931	[1],[3]
Posted Collateral	0	[3]
Additional Collateral, Aggregate Fair Value	0	[3]
Electric portfolio [Member] | External Credit Rating, Investment Grade [Member]	'
Derivative [Line Items]	'
Derivative, Credit Risk Exposure, Percentage	99.90%
Electric portfolio [Member] | External Credit Rating, Non Investment Grade [Member]	'
Derivative [Line Items]	'
Derivative, Credit Risk Exposure, Percentage	0.10%
Natural gas portfolio [Member] | Credit rating [Member]	'
Derivative [Line Items]	'
Posted Collateral	$1,000	[2]
[1]	1B 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]	2B 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]	3B Collateral requirements may vary, based on changes in the forward value of underlying transactions relative to contractually defined collateral thresholds.

Fair_Value_Measurements_Carryi

Fair Value Measurements Carrying Value (Details) (Carrying Value [Member], USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
PUGET ENERGY [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	$23,581	$44,302
Restricted Cash	25,437	7,171
Notes Receivable and Other	54,542	53,449
Total assets	103,560	104,922
Liabilities:	'	'
Short-term Debt	0	162,000
Total liabilities	0	162,000
PUGET ENERGY [Member] | Level 1 [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	23,581	44,302
Restricted Cash	25,437	7,171
Notes Receivable and Other	0	0
Total assets	49,018	51,473
Liabilities:	'	'
Short-term Debt	0	162,000
Total liabilities	0	162,000
PUGET ENERGY [Member] | Level 2 [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	0	0
Restricted Cash	0	0
Notes Receivable and Other	54,542	53,449
Total assets	54,542	53,449
Liabilities:	'	'
Short-term Debt	0	0
Total liabilities	0	0
Subsidiaries [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	23,556	44,111
Restricted Cash	25,437	7,171
Notes Receivable and Other	54,542	53,449
Total assets	103,535	104,731
Liabilities:	'	'
Short-term Debt	0	162,000
Short-term Debt owed by PSE to PE	29,598	29,598
Total liabilities	29,598	191,598
Subsidiaries [Member] | Level 1 [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	23,556	44,111
Restricted Cash	25,437	7,171
Notes Receivable and Other	0	0
Total assets	48,993	51,282
Liabilities:	'	'
Short-term Debt	0	162,000
Short-term Debt owed by PSE to PE	0	0
Total liabilities	0	162,000
Subsidiaries [Member] | Level 2 [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	0	0
Restricted Cash	0	0
Notes Receivable and Other	54,542	53,449
Total assets	54,542	53,449
Liabilities:	'	'
Short-term Debt	0	0
Short-term Debt owed by PSE to PE	29,598	29,598
Total liabilities	$29,598	$29,598

Fair_Value_Measurements_Debt_a

Fair Value Measurements Debt at at Carrying and Fair Value (Details) (Discounted cash flow [Member], USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
PUGET ENERGY [Member] | Carrying Value [Member]	'	'
Liabilities:	'	'
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	$5,235,259	$5,232,476
PUGET ENERGY [Member] | Carrying Value [Member] | Level 2 [Member]	'	'
Liabilities:	'	'
Junior subordinated notes	250,000	250,000
Long-term debt (fixed-rate), net of discount	4,686,259	4,683,476
Long Term Debt (variable rate) net of discount	299,000	299,000
PUGET ENERGY [Member] | Fair Value [Member]	'	'
Liabilities:	'	'
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	6,454,484	6,162,680
PUGET ENERGY [Member] | Fair Value [Member] | Level 2 [Member]	'	'
Liabilities:	'	'
Junior subordinated notes	280,137	269,366
Long-term debt (fixed-rate), net of discount	5,875,347	5,594,314
Long Term Debt (variable rate) net of discount	299,000	299,000
Subsidiaries [Member] | Carrying Value [Member]	'	'
Liabilities:	'	'
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	3,763,258	3,763,258
Subsidiaries [Member] | Carrying Value [Member] | Level 2 [Member]	'	'
Liabilities:	'	'
Junior subordinated notes	250,000	250,000
Long-term debt (fixed-rate), net of discount	3,513,258	3,513,258
Subsidiaries [Member] | Fair Value [Member]	'	'
Liabilities:	'	'
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	4,519,878	4,307,821
Subsidiaries [Member] | Fair Value [Member] | Level 2 [Member]	'	'
Liabilities:	'	'
Junior subordinated notes	280,137	269,366
Long-term debt (fixed-rate), net of discount	$4,239,741	$4,038,455

Fair_Value_Measurements_Assets

Fair Value Measurements Assets and Liabilities (Details) (USD $)

3 Months Ended

3 Months Ended

3 Months Ended

Mar. 31, 2014

Mar. 31, 2013

Jun. 30, 2013

Mar. 31, 2014

Mar. 31, 2013

Jun. 30, 2013

Mar. 31, 2014

Mar. 31, 2013

Jun. 30, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Electric portfolio [Member]

Electric portfolio [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

Natural gas portfolio [Member]

Natural gas portfolio [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Total [Member]

Total [Member]

Total [Member]

Total [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Total [Member]

Total [Member]

Total [Member]

Total [Member]

Total [Member]

Total [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Electric portfolio [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

Natural gas portfolio [Member]

Electric portfolio [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

Natural gas portfolio [Member]

Electric portfolio [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

Natural gas portfolio [Member]

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

'

'

'

'

'

'

'

'

'

'

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'

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'

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'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

Unrealized Gain (Loss) on Derivatives and Commodity Contracts

'

'

'

($9,200,000)

$1,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

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'

'

'

'

'

'

'

'

'

'

Derivative Assets

'

'

'

'

'

'

'

'

'

51,709,000

26,600,000

'

'

'

'

'

'

'

'

'

'

'

'

44,119,000

20,109,000

18,866,000

14,661,000

25,253,000

5,448,000

7,590,000

6,491,000

5,040,000

[1]

3,818,000

2,550,000

[1]

2,673,000

51,709,000

26,600,000

23,906,000

18,479,000

27,803,000

8,121,000

Derivative Liabilities

'

'

'

'

'

'

'

'

'

'

'

12,126,000

13,223,000

12,126,000

13,223,000

0

0

0

0

12,126,000

13,223,000

12,126,000

13,223,000

25,232,000

50,715,000

14,719,000

18,073,000

10,513,000

32,642,000

23,299,000

22,273,000

19,646,000

[1]

19,239,000

3,653,000

[1]

3,034,000

48,531,000

72,988,000

34,365,000

37,312,000

14,166,000

35,676,000

Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]

'

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'

'

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'

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'

'

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'

'

'

'

'

'

'

'

Balance at beginning of period

-15,782,000

-35,526,000

-27,976,000

-15,421,000

-33,924,000

-26,442,000

-361,000

-1,602,000

-1,534,000

'

'

'

'

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'

'

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'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

Included in earnings

-2,745,000

[2]

1,598,000

[2]

'

-2,745,000

[2]

1,598,000

[2]

'

0

[2]

0

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Included in regulatory assets/liabilities

259,000

674,000

'

0

0

'

259,000

674,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Settlements

-89,000

[3]

5,651,000

[3]

'

321,000

[3]

6,384,000

[3]

'

-410,000

[3]

-733,000

[3]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Transferred into Level 3

2,515,000

-7,700,000

'

3,100,000

-7,700,000

'

-585,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Transferred out of Level 3

133,000

7,327,000

'

139,000

7,200,000

'

-6,000

127,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at end of period

($15,709,000)

'

($27,976,000)

($14,606,000)

'

($26,442,000)

($1,103,000)

'

($1,534,000)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

1B The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions

[2]

1B 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 $(9.2) million and $1.4 million for the three months ended MarchB 31, 2014 and 2013, respectively.

[3]

2 The Company had no purchases, sales or issuances during the reported periods.

Fair_Value_Measurements_Valuat

Fair Value Measurements Valuation Technicques for Measurement with Unobservable Inputs (Details) (USD $)

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Commodity Contract [Member]

Commodity Contract [Member]

Electric portfolio [Member]

Electric portfolio [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

Natural gas portfolio [Member]

Natural gas portfolio [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Electric portfolio [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

Natural gas portfolio [Member]

Discounted cash flow [Member]

Discounted cash flow [Member]

Discounted cash flow [Member]

Discounted cash flow [Member]

Discounted cash flow [Member]

Discounted cash flow [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Low [Member]

High [Member]

Weighted Average [Member]

Low [Member]

High [Member]

Weighted Average [Member]

Subsidiaries [Member]

Subsidiaries [Member]

PUGET ENERGY [Member]

PUGET ENERGY [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Assets

'

$51,709,000

$26,600,000

'

'

'

'

'

'

$7,590,000

$6,491,000

'

'

$5,040,000

[1]

$3,818,000

$2,550,000

[1]

$2,673,000

Derivative Liabilities

'

'

'

'

'

'

'

'

'

23,299,000

22,273,000

0

0

19,646,000

[1]

19,239,000

3,653,000

[1]

3,034,000

Price (per MWh)

'

'

'

4.38

49.95

35.67

'

'

'

'

'

'

'

'

'

'

'

Price (per MMBtu)

'

'

'

'

'

'

3.62

4.63

4.04

'

'

'

'

'

'

'

'

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

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

$12,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

1B The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions

Retirement_Benefits_Net_Period

Retirement Benefits Net Periodic Benefit Cost (Details) (USD $)	3 Months Ended	12 Months Ended	3 Months Ended	12 Months Ended	3 Months Ended	12 Months Ended	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
	Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	Other Benefit [Member]	Other Benefit [Member]	PUGET ENERGY [Member]	PUGET ENERGY [Member]	PUGET ENERGY [Member]	PUGET ENERGY [Member]	PUGET ENERGY [Member]	PUGET ENERGY [Member]	Subsidiaries [Member]	Subsidiaries [Member]	Subsidiaries [Member]	Subsidiaries [Member]	Subsidiaries [Member]	Subsidiaries [Member]
							Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	Other Benefit [Member]	Other Benefit [Member]	Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	Other Benefit [Member]	Other Benefit [Member]
Components of net periodic benefit cost:	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'
Service cost	($4,512)	($19,285)	($261)	($1,498)	($29)	($134)	$4,512	$4,709	$261	$375	$29	$34	$4,512	$4,709	$261	$375	$29	$34
Interest cost	-7,055	-24,754	-577	-2,045	-183	-664	7,055	6,194	577	511	183	176	7,055	6,194	577	511	183	176
Expected return on plan assets	'	'	'	'	'	'	-10,721	-9,851	0	0	-133	-108	-10,919	-10,249	0	0	-133	-108
Amortization of prior service cost	'	'	'	'	'	'	-495	-495	11	-4	0	0	-393	-393	11	-4	1	8
Amortization of net loss (gain)	'	'	'	'	'	'	0	650	228	365	-66	17	3,239	5,085	365	548	-143	-34
Defined Benefit Plan, Net Periodic Benefit Cost	'	'	'	'	'	'	$351	$1,207	$1,077	$1,247	$13	$119	$3,494	$5,346	$1,214	$1,430	($63)	$76

Retirement_Benefits_Change_in_

Retirement Benefits Change in Net Benefit Obligation (Details) (USD $)	3 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Qualified Pension Benefits [Member]	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'
Benefit obligation at beginning of period	$573,317	$616,290
Service cost	-4,512	-19,285
Interest cost	7,055	24,754
Amendments	0	0
Actuarial loss/(gain)	0	-48,559
Benefits paid	-10,001	-38,453
Medicare part D subsidiary received	0	0
Benefit obligation at end of period	574,883	573,317
SERP Pension Benefits [Member]	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'
Benefit obligation at beginning of period	47,279	51,795
Service cost	-261	-1,498
Interest cost	577	2,045
Amendments	0	478
Actuarial loss/(gain)	0	-1,687
Benefits paid	-460	-6,850
Medicare part D subsidiary received	0	0
Benefit obligation at end of period	47,657	47,279
Other Benefit [Member]	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'
Benefit obligation at beginning of period	14,939	17,672
Service cost	-29	-134
Interest cost	183	664
Amendments	0	0
Actuarial loss/(gain)	0	-2,240
Benefits paid	-391	-1,536
Medicare part D subsidiary received	42	245
Benefit obligation at end of period	$14,802	$14,939

Retirement_Benefits_Activity_D

Retirement Benefits Activity (Details) (USD $)	3 Months Ended							12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014
	Qualified Pension Benefits [Member]	SERP Pension Benefits [Member]	Other Benefit [Member]	Subsidiaries [Member]	Scenario, Forecast [Member]	Scenario, Forecast [Member]	Scenario, Forecast [Member]	Scenario, Forecast [Member]
					Qualified Pension Benefits [Member]	SERP Pension Benefits [Member]	Other Benefit [Member]	Subsidiaries [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'	'	'	'	'
Defined Contribution Plan, Employer Matching Contribution, Percent	'	'	'	1.00%	'	'	'	4.00%
Aggregate expected contributions	'	'	'	'	$12	$4	$0.40	'
Company Contribution	$3	$0.50	$0.20	'	'	'	'	'

Regulation_and_Rates_Details

Regulation and Rates (Details) (USD $)

11 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Jul. 02, 2013

Jan. 02, 2014

Jan. 02, 2014

Jul. 02, 2013

Jul. 02, 2013

Jul. 02, 2013

Jul. 02, 2013

Nov. 01, 2013

Nov. 01, 2013

Dec. 31, 2014

1-May-14

1-May-14

1-May-14

1-May-14

Subsidiaries [Member]

Subsidiaries [Member]

Decoupling Mechanism [Member]

Decoupling Mechanism [Member]

Decoupling Mechanism [Member]

Decoupling Mechanism [Member]

Expedited Rate Filing [Member]

Expedited Rate Filing [Member]

Power Cost Only Rate Case (PCORC) [Member]

Purchased Gas Adjustment (PGA) [Member]

Scenario, Forecast [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Electric [Member]

Natural Gas [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Decoupling Mechanism [Member]

Decoupling Mechanism [Member]

Property tax tracker [Member] [Domain] [Domain]

Property tax tracker [Member] [Domain] [Domain]

Electric [Member]

Natural Gas [Member]

Electric [Member]

Natural Gas [Member]

Electric [Member]

Natural Gas [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Subsidiaries [Member]

Electric [Member]

Natural Gas [Member]

Electric [Member]

Natural Gas [Member]

Regulatory Assets [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'11 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

$34.60

'

'

'

'

'

'

'

'

'

$37.80

'

'

'

'

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

23.8

'

'

'

'

'

'

'

'

'

20.6

'

'

'

'

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

2.76%

'

'

'

'

'

'

'

'

'

-0.26%

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

58.5

'

'

'

'

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

'

'

'

'

$21.40

$10.80

$30.70

($2)

($10.50)

$4

'

$10.60

($1)

$11

$5.60

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

'

'

3.00%

2.20%

1.00%

1.10%

1.50%

-0.20%

-0.50%

0.40%

'

0.50%

-0.10%

0.50%

0.60%

Rate Case, Approved Effective Weighted Cost of Capital

'

7.77%

'

'

'

'

'

'

'

'

'

'

'

'

'

Rate Case, Approved Effective Common Equity in Capital Structure

'

48.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Rate Case, Approved Effective Return on Equity

'

9.80%

'

'

'

'

'

'

'

'

'

'

'

'

'

Litigation_Details

Litigation (Details) (USD $)	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2013	Mar. 06, 2013	Mar. 06, 2013	Mar. 06, 2013
		Colstrip Units 1 and 2 [Member]	Colstrip Units 3 and 4 [Member]	Pending Litigation [Member]	Pending Litigation [Member]	Pending Litigation [Member]	Pending Litigation [Member]	Pending Litigation [Member]
						Sierra Club and Montana Environmental Information Center [Member]	Failure to Update Title V Permit [Member]	Major Modifications to Title V Permit [Member]
							Sierra Club and Montana Environmental Information Center [Member]	Sierra Club and Montana Environmental Information Center [Member]
							claim	claim
Loss Contingencies [Line Items]	'	'	'	'	'	'	'	'
Residential Exchange Program Repayment	$62,900,000	'	'	'	'	'	'	'
Ownership interest (percent)	'	50.00%	25.00%	'	'	'	'	'
Numbe of claims	'	'	'	'	'	'	1	36
Damages sought, civil penalties to be used for beneficial mitigation projects	'	'	'	'	'	100,000	'	'
Litigation claims accrual	'	'	'	$1,360,000	$1,380,000	'	'	'

Accumulated_Other_Comprehensiv2

Accumulated Other Comprehensive Income - Changes by Component (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014
In Thousands, unless otherwise specified			Subsidiaries [Member]	Subsidiaries [Member]	Accumulated Defined Benefit Plans Adjustment [Member]	Accumulated Defined Benefit Plans Adjustment [Member]	Derivative [Member]	Derivative [Member]	Interest Rate Swap [Member]	Interest Rate Swap [Member]	Comprehensive Income [Member]	Comprehensive Income [Member]
					PUGET ENERGY [Member]	Subsidiaries [Member]	PUGET ENERGY [Member]	Subsidiaries [Member]	PUGET ENERGY [Member]	Subsidiaries [Member]	PUGET ENERGY [Member]	Subsidiaries [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'	'	'	'	'	'	'	'	'	'
Beginning balance	$47,947	$47,715	($92,941)	($95,739)	$48,514	($87,405)	($705)	($2,027)	($94)	($6,307)	$47,715	($95,739)
Other comprehensive income (loss) before reclassifications	'	'	'	'	0	0	0	0	0	0	0	0
Amounts reclassified from accumulated other comprehensive income (loss), net of tax	'	'	'	'	-209	2,001	347	718	94	79	232	2,798
Net current-period other comprehensive income (loss)	'	'	'	'	-209	2,001	347	718	94	79	232	2,798
Ending balance	$47,947	$47,715	($92,941)	($95,739)	$48,305	($85,404)	($358)	($1,309)	$0	($6,228)	$47,947	($92,941)

Accumulated_Other_Comprehensiv3

Accumulated Other Comprehensive Income - Reclassification Location (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Comprehensive income (loss)	$107,824		$168,569
Subsidiaries [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Comprehensive income (loss)	123,881		185,214
Reclassification out of Accumulated Other Comprehensive Income [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Comprehensive income (loss)	-232		-1,094
Reclassification out of Accumulated Other Comprehensive Income [Member] | Subsidiaries [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Comprehensive income (loss)	-2,798		-5,276
Interest Rate Contract [Member] | Interest Expense [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-144		-1,314
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	50		460
Comprehensive income (loss)	-94		-854
Interest Rate Contract [Member] | Interest Expense [Member] | Subsidiaries [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-122		-122
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	43		43
Comprehensive income (loss)	-79		-79
Electric Derivative [Member] | Purchased Electricity [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-534		164
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	187		-57
Comprehensive income (loss)	-347		107
Electric Derivative [Member] | Purchased Electricity [Member] | Subsidiaries [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-1,104		-2,786
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	386		975
Comprehensive income (loss)	-718		-1,811
Qualified Pension Benefits [Member] | Pension Cost [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	322		-533
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	-113		186
Comprehensive income (loss)	209		-347
Qualified Pension Benefits [Member] | Pension Cost [Member] | Subsidiaries [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-3,080		-5,210
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	1,079		1,824
Comprehensive income (loss)	-2,001		-3,386
Amortization of Net Gain (Loss) [Member] | Pension Cost [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-162	[1]	-1,032	[1]
Amortization of Net Gain (Loss) [Member] | Pension Cost [Member] | Subsidiaries [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	-3,461	[2]	-5,599	[2]
Amortization of Prior Service Cost [Member] | Pension Cost [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	484	[1]	499	[1]
Amortization of Prior Service Cost [Member] | Pension Cost [Member] | Subsidiaries [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	$381	[2]	$389	[2]
[1]	(a)B These accumulated other comprehensive income components are included in the computation of net periodic pension cost (see Note 4 for additional details).
[2]	(a) These accumulated other comprehensive income components are included in the computation of net periodic pension cost (see Note 4 for additional details).

Other_Jefferson_County_Public_

Other Jefferson County Public Utility District (Details) (Jefferson County Public Utility District [Member], USD $)	Oct. 31, 2013	Mar. 30, 2013	Mar. 28, 2014	Oct. 31, 2013	Mar. 28, 2014	Oct. 31, 2013
In Millions, unless otherwise specified			Subsidiaries [Member]	Subsidiaries [Member]	Customers [Member]	Customers [Member]
Significant Acquisitions and Disposals [Line Items]	'	'	'	'	'	'
Property, Plant and Equipment, Net Book Value	'	$46.70	'	'	'	'
Significant Acquisitions and Disposals, Gain (Loss) on Sale or Disposal, Pretax	'	$60	$3	$45	$57	$15
Accounting Petition, Requested Amortization Period	'48 months	'	'	'	'	'

Other_Bond_Issuances_Details

Other Bond Issuances (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2013	23-May-13	23-May-13	23-May-13	Mar. 01, 2023
	Pollution Control Bonds [Member]	Pollution Control Bonds [Member]	5.000% Series Due 2031 [Member]	3.910% Series Due 2031 [Member]	Scenario, Forecast [Member]
		Subsidiaries [Member]	Subsidiaries [Member]	Subsidiaries [Member]	Pollution Control Bonds [Member]
					Subsidiaries [Member]
Debt Instrument [Line Items]	'	'	'	'	'
Long-term Debt, Gross	'	$161.90	'	'	'
Debt Instrument, Interest Rate, Stated Percentage	'	'	5.01%	3.91%	'
Debt Instrument, Redemption Payment Term, Percentage of Principal Amount	'	'	'	'	100.00%
Gains (Losses) on Extinguishment of Debt	($18)	'	'	'	'