Puget Energy (PSD) 10-Q31 Jul 142014 Q2 Quarterly reportFinancial data

Company Profile

Document_And_Entity_Informatio

Document And Entity Information	6 Months Ended
Document And Entity Information	Jun. 30, 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	'Q2
Document Type	'10-Q
Amendment Flag	'false
Document Period End Date	30-Jun-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	30-Jun-14

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Operating revenue:	'	'	'	'
Electric	$475,580	$461,657	$1,109,133	$1,076,291
Gas	183,935	180,728	571,378	565,493
Other	3,401	101	7,780	520
Total operating revenue	662,916	642,486	1,688,291	1,642,304
Energy costs:	'	'	'	'
Purchased electricity	114,627	112,543	295,785	287,587
Electric generation fuel	34,795	40,737	110,232	99,823
Residential exchange	-23,621	-14,963	-53,624	-37,515
Purchased gas	76,272	79,487	267,578	269,470
Unrealized (gain) loss on derivative instruments, net	-17,094	27,376	-24,934	-48,316
Utility operations and maintenance	134,883	130,286	278,960	259,521
Non-utility expense and other	2,293	-959	5,712	-1,953
Depreciation	92,462	90,301	183,646	178,480
Amortization	12,735	6,433	23,270	12,177
Conservation amortization	22,526	22,469	51,508	56,576
Taxes other than income taxes	67,772	53,695	168,590	153,638
Total operating expenses	517,650	547,405	1,306,723	1,229,488
Operating income	145,266	95,081	381,568	412,816
Other income (deductions):	'	'	'	'
Other income	4,621	10,844	8,863	22,857
Other expense	-1,644	-1,454	-3,226	-2,996
Non-hedged interest rate derivative expense	-1,360	1,232	-2,107	2,260
Interest charges:	'	'	'	'
AFUDC	1,562	3,162	2,714	7,810
Interest expense	-92,173	-108,917	-182,428	-204,733
Income (loss) before income taxes	56,272	-52	205,384	238,014
Income tax (benefit) expense	15,159	-957	56,679	69,634
Net income (loss)	41,113	905	148,705	168,380
Subsidiaries [Member]	'	'	'	'
Operating revenue:	'	'	'	'
Electric	475,580	461,657	1,109,133	1,076,291
Gas	183,935	180,728	571,378	565,493
Other	3,401	101	7,780	409
Total operating revenue	662,916	642,486	1,688,291	1,642,193
Energy costs:	'	'	'	'
Purchased electricity	114,627	112,543	295,785	287,587
Electric generation fuel	34,795	40,737	110,232	99,823
Residential exchange	-23,621	-14,963	-53,624	-37,515
Purchased gas	76,272	79,487	267,578	269,470
Unrealized (gain) loss on derivative instruments, net	-17,094	27,376	-24,364	-45,365
Utility operations and maintenance	134,883	130,286	278,960	259,521
Non-utility expense and other	5,374	3,028	11,548	6,120
Depreciation	92,462	90,301	183,646	178,480
Amortization	12,735	6,433	23,270	12,177
Conservation amortization	22,526	22,469	51,508	56,576
Taxes other than income taxes	67,772	53,695	168,590	153,638
Total operating expenses	520,731	551,392	1,313,129	1,240,512
Operating income	142,185	91,094	375,162	401,681
Other income (deductions):	'	'	'	'
Other income	4,621	10,846	8,860	22,857
Other expense	-1,644	-1,454	-3,226	-2,996
Interest charges:	'	'	'	'
AFUDC	1,562	3,162	2,714	7,810
Interest expense	-65,522	-65,773	-129,659	-131,749
Interest expense on parent note	-27	-32	-52	-61
Income (loss) before income taxes	81,175	37,843	253,799	297,542
Income tax (benefit) expense	23,341	11,180	74,883	90,941
Net income (loss)	$57,834	$26,663	$178,916	$206,601

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Parent [Line Items]	'	'	'	'
Net income (loss)	$41,113	$905	$148,705	$168,380
Other comprehensive income (loss):	'	'	'	'
Net unrealized gain (loss) from pension and postretirement plans, net of tax	-783	-1,107	-992	-760
Other Comprehensive Income (Loss), Reclassification Adjustment on Derivatives Included in Net Income, Net of Tax	0	0	347	-107
Other Comprehensive Income Reclassification Of Net Unrealized Gain Loss On Interest Rate Swaps During Period Net Of Tax	0	861	94	1,715
Other comprehensive income (loss)	-783	-246	-551	848
Comprehensive income (loss)	40,330	659	148,154	169,228
Subsidiaries [Member]	'	'	'	'
Parent [Line Items]	'	'	'	'
Net income (loss)	57,834	26,663	178,916	206,601
Other comprehensive income (loss):	'	'	'	'
Net unrealized gain (loss) from pension and postretirement plans, net of tax	1,424	1,879	3,425	5,265
Other Comprehensive Income (Loss), Reclassification Adjustment on Derivatives Included in Net Income, Net of Tax	0	0	718	1,811
Amortization Of Financing Cash Flow Hedge Contracts To Earnings During Period Net Of Tax	79	79	158	158
Other comprehensive income (loss)	1,503	1,958	4,301	7,234
Comprehensive income (loss)	$59,337	$28,621	$183,217	$213,835

CONSOLIDATED_STATEMENTS_OF_COM1

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Net unrealized gain (loss) from pension and postretirement plans, tax	($421)	($596)	($534)	($409)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	0	0	187	-57
Other Comprehensive Income Reclassification Of Net Unrealized Gain Loss On Interest Rate Swaps During Period Tax	0	464	50	924
Subsidiaries [Member]	'	'	'	'
Net unrealized gain (loss) from pension and postretirement plans, tax	766	1,011	1,844	2,835
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	0	0	386	975
Amortization of Financing Cash Flow Hedge Contracts to Earnings Tax	$43	$43	$85	$85

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Utility plant (at original cost, including construction work in progress):	'	'
Electric plant	$7,046,429	$7,019,853
Gas plant	2,602,397	2,528,629
Common plant	456,383	504,036
Less: Accumulated depreciation and amortization	-1,478,202	-1,373,178
Net utility plant	8,627,007	8,679,340
Other property and investments:	'	'
Goodwill	1,656,513	1,656,513
Other property and investments	99,877	100,332
Total other property and investments	1,756,390	1,756,845
Current assets:	'	'
Cash and cash equivalents	84,707	44,302
Restricted cash	54,964	7,171
Accounts receivable, net of allowance for doubtful accounts	287,374	408,512
Unbilled revenue	112,304	219,884
Purchased Gas Adjustment Receivable	12,539	0
Materials and supplies, at average cost	82,658	88,140
Fuel and gas inventory, at average cost	64,334	66,717
Unrealized gain on derivative instruments	44,405	18,867
Income taxes	0	297
Prepaid expense and other	20,043	18,787
Power contract acquisition adjustment gain	49,020	48,509
Deferred income taxes	73,902	86,004
Total current assets	886,250	1,007,190
Other long-term and regulatory assets:	'	'
Regulatory asset for deferred income taxes	150,083	146,867
Regulatory assets related to power contracts	31,311	33,753
Other regulatory assets	733,281	749,382
Unrealized gain on derivative instruments	7,678	7,733
Power contract acquisition adjustment gain	370,468	394,556
Other	137,336	130,909
Total other long-term and regulatory assets	1,430,157	1,463,200
Total assets	12,699,804	12,906,575
Capitalization:	'	'
Common stock	0	0
Additional paid-in capital	3,308,957	3,308,957
Earnings reinvested in the business	333,933	323,007
Accumulated Other Comprehensive Income (Loss), Net of Tax	47,164	47,715
Total common shareholder's equity	3,690,054	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	-224,230	-229,796
Total long-term debt	5,238,042	5,232,476
Total capitalization	8,928,096	8,912,155
Current liabilities:	'	'
Accounts payable	245,760	296,681
Short-term debt	0	162,000
Purchased gas adjustment liability	0	5,938
Accrued expenses:	'	'
Taxes	92,023	109,559
Salaries and wages	32,256	38,491
Interest	78,759	79,303
Unrealized loss on derivative instruments	23,690	48,049
Power contract acquisition adjustment loss	3,720	3,937
Other	68,671	60,335
Total current liabilities	544,879	804,293
Long-term and regulatory liabilities:	'	'
Deferred income taxes	1,534,501	1,487,005
Unrealized loss on derivative instruments	21,761	38,162
Power Cost Adjustment Mechanism	5,445	5,345
Regulatory liabilities	694,486	689,060
Regulatory liabilities related to power contracts	419,488	443,065
Power contract acquisition adjustment loss	27,592	29,816
Other deferred credits	523,556	497,674
Total long-term and regulatory liabilities	3,226,829	3,190,127
Commitments and contingencies	'	'
Total capitalization and liabilities	12,699,804	12,906,575
Subsidiaries [Member]	'	'
Utility plant (at original cost, including construction work in progress):	'	'
Electric plant	9,296,198	9,276,400
Gas plant	3,207,261	3,134,880
Common plant	497,495	565,072
Less: Accumulated depreciation and amortization	-4,373,947	-4,297,012
Net utility plant	8,627,007	8,679,340
Other property and investments:	'	'
Other property and investments	91,465	91,919
Total other property and investments	91,465	91,919
Current assets:	'	'
Cash and cash equivalents	69,160	44,111
Restricted cash	54,964	7,171
Accounts receivable, net of allowance for doubtful accounts	287,848	408,827
Unbilled revenue	112,304	219,884
Purchased Gas Adjustment Receivable	12,539	'
Materials and supplies, at average cost	82,658	88,140
Fuel and gas inventory, at average cost	61,555	63,914
Unrealized gain on derivative instruments	44,405	18,867
Income taxes	0	297
Prepaid expense and other	20,043	18,770
Deferred income taxes	129,122	141,058
Total current assets	874,598	1,011,039
Other long-term and regulatory assets:	'	'
Regulatory asset for deferred income taxes	149,573	146,350
Other regulatory assets	733,215	749,382
Unrealized gain on derivative instruments	7,678	7,733
Other	130,131	123,125
Total other long-term and regulatory assets	1,020,597	1,026,590
Total assets	10,613,667	10,808,888
Capitalization:	'	'
Common stock	859	859
Additional paid-in capital	3,246,205	3,246,205
Earnings reinvested in the business	264,720	289,432
Accumulated Other Comprehensive Income (Loss), Net of Tax	-91,438	-95,739
Total common shareholder's equity	3,420,346	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	7,183,604	7,204,015
Current liabilities:	'	'
Accounts payable	245,753	296,675
Short-term debt	0	162,000
Short-term note owed to parent	28,933	29,598
Purchased gas adjustment liability	0	5,938
Accrued expenses:	'	'
Taxes	92,023	109,559
Salaries and wages	32,256	38,491
Interest	55,216	55,262
Unrealized loss on derivative instruments	16,895	41,465
Other	68,671	60,334
Total current liabilities	539,747	799,322
Long-term and regulatory liabilities:	'	'
Deferred income taxes	1,653,337	1,584,850
Unrealized loss on derivative instruments	16,208	31,523
Power Cost Adjustment Mechanism	5,445	5,345
Regulatory liabilities	691,642	686,176
Other deferred credits	523,684	497,657
Total long-term and regulatory liabilities	2,890,316	2,805,551
Commitments and contingencies	'	'
Total capitalization and liabilities	$10,613,667	$10,808,888

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
ASSETS	'	'
Construction work in progress	$313,227	$310,318
Current assets:	'	'
Allowance for doubtful accounts	10,517	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	313,227	310,318
Current assets:	'	'
Allowance for doubtful accounts	$10,517	$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 $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Operating activities:	'	'
Net income (loss)	$148,705	$168,380
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation	183,646	178,480
Amortization	23,270	12,177
Conservation amortization	51,508	56,576
Deferred income taxes and tax credits, net	56,679	69,635
Net unrealized (gain) loss on derivative instruments	-25,664	-53,496
Derivative contracts classified as financing activities due to merger	8,026	26,013
AFUDC - Equity	-3,405	-11,222
Funding of pension liability	-6,000	-10,200
Regulatory Assets	-80,365	-66,102
Regulatory liabilities	3,668	10,341
Other long-term assets	-6,477	10,842
Other long-term liabilities	37,739	54,837
Change in certain current assets and liabilities:	'	'
Accounts receivable and unbilled revenue	228,718	136,457
Materials and supplies	5,482	-2,184
Fuel and gas inventory	2,359	11,104
Income taxes	297	4,795
Prepayments and other	-1,273	-7,340
Purchased gas adjustment	-18,477	-18,078
Accounts payable	-64,794	-74,666
Taxes payable	-17,536	-11,589
Accrued expenses and other	-8,884	-15,507
Net cash provided by operating activities	517,222	469,253
Investing activities:	'	'
Construction expenditures - excluding equity AFUDC	-217,381	-326,082
Treasury grant payment received	107,794	0
Proceeds from disposition of assets	0	108,166
Restricted cash	-47,793	-1,023
Other	-11,058	-5,119
Net cash used in investing activities	-168,438	-224,058
Financing activities:	'	'
Change in short-term debt and leases, net	-165,789	-184,789
Dividends paid	-137,779	-84,609
Long-term notes and bonds issued	299,000	161,860
Redemption of bonds and notes	-299,000	-216,860
Derivative contracts classified as financing activities due to merger	-8,026	-26,013
Issuance cost of bonds and other	3,215	-2,722
Net cash provided by (used in) financing activities	-308,379	-353,133
Net increase (decrease) in cash and cash equivalents	40,405	-107,938
Cash and cash equivalents at beginning of period	44,302	135,542
Cash and cash equivalents at end of period	84,707	27,604
Supplemental cash flow information:	'	'
Cash payments for interest (net of capitalized interest)	172,106	162,588
Cash payments (refunds) for income taxes	0	-4,500
Subsidiaries [Member]	'	'
Operating activities:	'	'
Net income (loss)	178,916	206,601
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation	183,646	178,480
Amortization	23,270	12,177
Conservation amortization	51,508	56,576
Deferred income taxes and tax credits, net	74,883	90,940
Net unrealized (gain) loss on derivative instruments	-24,364	-45,365
AFUDC - Equity	-3,405	-11,222
Funding of pension liability	-6,000	-10,200
Regulatory Assets	-80,365	-66,102
Regulatory liabilities	3,668	10,341
Other long-term assets	-1,650	14,921
Other long-term liabilities	33,339	33,285
Change in certain current assets and liabilities:	'	'
Accounts receivable and unbilled revenue	228,559	130,617
Materials and supplies	5,482	-2,184
Fuel and gas inventory	2,359	11,104
Income taxes	297	4,795
Prepayments and other	-1,273	-7,340
Purchased gas adjustment	-18,477	-18,078
Accounts payable	-64,794	-68,819
Taxes payable	-17,536	-11,589
Accrued expenses and other	-9,620	-17,586
Net cash provided by operating activities	558,443	491,352
Investing activities:	'	'
Construction expenditures - excluding equity AFUDC	-217,381	-326,082
Treasury grant payment received	107,794	0
Proceeds from disposition of assets	0	108,166
Restricted cash	-47,793	-1,023
Other	-9,818	-4,902
Net cash used in investing activities	-167,198	-223,841
Financing activities:	'	'
Change in short-term debt and leases, net	-165,789	-184,789
Dividends paid	-203,628	-188,064
Loan from (payment to) parent	-665	0
Long-term notes and bonds issued	0	161,860
Redemption of bonds and notes	0	-161,860
Issuance cost of bonds and other	3,886	-2,725
Net cash provided by (used in) financing activities	-366,196	-375,578
Net increase (decrease) in cash and cash equivalents	25,049	-108,067
Cash and cash equivalents at beginning of period	44,111	135,530
Cash and cash equivalents at end of period	69,160	27,463
Supplemental cash flow information:	'	'
Cash payments for interest (net of capitalized interest)	123,345	122,892
Cash payments (refunds) for income taxes	$0	($4,500)

New_Accounting_Pronouncements

New Accounting Pronouncements	6 Months Ended
New Accounting Pronouncements	Jun. 30, 2014
New Accounting Pronouncements [Abstract]	'
New Accounting Pronouncements and Changes in Accounting Principles [Text Block]	'
	New Accounting Pronouncements

	In May 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2014-09, Revenue from Contracts with Customers, that outlines a single comprehensive model for use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry-specific guidance. The ASU is based on the principle that an entity should recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The ASU also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts, including significant judgments and changes in judgments and assets recognized from costs incurred to fulfill a contract.
	ASU 2014-09 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Early adoption of the ASU is not permitted. Entities have the option of using either a full retrospective or a modified retrospective approach for the adoption of the new standard. The company is currently evaluating the new guidance. At this time we can not determine the impact this standard will have on its consolidated financial statements.

Accounting_for_Derivative_Inst

Accounting for Derivative Instruments and Hedging Activities	6 Months Ended
	Jun. 30, 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 June 30, 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	June 30, 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	$	—		$	12,349		$450 million	$	—		$	13,223

	Electric portfolio derivatives	*	26,902			20,266			*	18,479			37,312

	Natural gas derivatives (MMBtus) 4	359.0 million	25,181			12,836			423.5 million	8,121			35,676

	Total derivative contracts		$	52,083		$	45,451			$	26,600		$	86,211

	Current		$	44,405		$	23,690			$	18,867		$	48,049

	Long-term		7,678			21,761				7,733			38,162

	Total derivative contracts		$	52,083		$	45,451			$	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 139.8 million One Million British Thermal Units (MMBtus) and purchased electricity of 5.5 million Megawatt Hours (MWhs) at June 30, 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 4.
	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
	June 30, 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	$	52,083		—			$	52,083		$	(22,446	)	$	—		$	29,637

	Liabilities
	Energy Derivative Contracts	$	33,102		$	—		$	33,102		$	(22,446	)	$	43		$	10,699

	Interest Rate Swaps 2	$	12,349		$	—		$	12,349		$	—		$	—		$	12,349


	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 June 30,						Six Months Ended
								June 30,
(Dollars in Thousands)	Location	2014			2013			2014			2013
Interest rate contracts:	Non-hedged interest rate swap	$	(1,360	)	$	1,232		$	(2,107	)	$	2,260
	(expense) income
	Interest expense	(718		)	1,902			(843		)	(676		)

Commodity contracts:

Electric derivatives	Unrealized gain (loss) on derivative instruments, net	17,094			(27,376		)	24,934			48,316

	Electric generation fuel	864			(930		)	8,691			(13,568		)

	Purchased electricity	(3,668		)	(3,704		)	1,715			(35,189		)

Total gain (loss) recognized in income on derivatives		$	12,212		$	(28,876	)	$	32,390		$	1,143




Puget Sound Energy		Three Months Ended June 30,						Six Months Ended
								June 30,
(Dollars in Thousands)	Location	2014			2013			2014			2013
Commodity contracts:
Electric derivatives	Unrealized gain (loss) on derivative instruments, net	$	17,094		$	(27,376	)	$	24,364		$	45,365

	Electric generation fuel	864			(930		)	8,691			(13,568		)

	Purchased electricity	(3,668		)	(3,704		)	1,715			(35,189		)

Total gain (loss) recognized in income on derivatives		$	14,290		$	(32,010	)	$	34,770		$	(3,392	)


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 six months ended June 30, 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 June 30,						Six Months Ended
								June 30,
(Dollars in Thousands)	Location	2014			2013			2014			2013
Interest rate contracts:	Interest expense	$	—		$	(1,325	)	$	(144	)	$	(2,639	)

Commodity contracts:
Electric derivatives	Electric generation fuel	—			—			—			—

	Purchased electricity	—			—			(534		)	164

Total		$	—		$	(1,325	)	$	(678	)	$	(2,475	)




Puget Sound Energy		Three Months Ended June 30,						Six Months Ended
								June 30,
(Dollars in Thousands)	Location	2014			2013			2014			2013
Interest rate contracts:	Interest expense	$	(122	)	$	(122	)	$	(244	)	$	(244	)
Commodity contracts:
Electric derivatives	Electric generation fuel	—			—			—			—

	Purchased electricity	—			—			(1,104		)	(2,786		)

Total		$	(122	)	$	(122	)	$	(1,348	)	$	(3,030	)

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 June 30, 2014, approximately 99.9% of the Company's energy portfolio exposure, excluding NPNS transactions, is with counterparties that are rated at least investment grade and 0.1% are either rated below investment grade or not rated. The Company assesses credit risk internally for counterparties that are not rated by the major rating agencies.
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 June 30, 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 June 30, 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 June 30, 2014:



Puget Energy and Puget Sound Energy	Fair Value 1			Posted			Contingent
Contingent Feature
(Dollars in Thousands)	Liability			Collateral			Collateral
Credit rating 2	$	(6,909	)	$	—		$	6,909

Requested credit for adequate assurance	(10,207		)	—			—

Forward value of contract 3	(43		)	43			—

Total	$	(17,159	)	$	43		$	6,909

__________

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	6 Months Ended
	Jun. 30, 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 June 30, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	84,707		$	—		$	84,707		$	44,302		$	—		$	44,302

	Restricted Cash	54,964			—			54,964			7,171			—			7,171

	Notes Receivable and Other	—			52,692			52,692			—			53,449			53,449

	Total assets	$	139,671		$	52,692		$	192,363		$	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 June 30, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	69,160		$	—		$	69,160		$	44,111		$	—		$	44,111

	Restricted Cash	54,964			—			54,964			7,171			—			7,171

	Notes Receivable and Other	—			52,692			52,692			—			53,449			53,449

	Total assets	$	124,124		$	52,692		$	176,816		$	51,282		$	53,449		$	104,731

	Liabilities:
	Short-term debt	$	—		$	—		$	—		$	162,000		$	—		$	162,000

	Short-term debt owed to parent	—			28,933			28,933			—			29,598			29,598

	Total liabilities	$	—		$	28,933		$	28,933		$	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		June 30, 2014						December 31, 2013
(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
		Value			Value			Value			Value
Liabilities:
Junior subordinated notes	2	$	250,000		$	296,696		$	250,000		$	269,366

Long-term debt (fixed-rate), net of discount	2	4,689,042			6,018,770			4,683,476			5,594,314

Long-term debt (variable-rate)	2	299,000			299,000			299,000			299,000

Total		$	5,238,042		$	6,614,466		$	5,232,476		$	6,162,680


Puget Sound Energy		June 30, 2014						December 31, 2013
(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
		Value			Value			Value			Value
Liabilities:
Junior subordinated notes	2	$	250,000		$	296,696		$	250,000		$	269,366

Long-term debt (fixed-rate), net of discount	2	3,513,258			4,352,590			3,513,258			4,038,455

Total		$	3,763,258		$	4,649,286		$	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 June 30, 2014									At December 31, 2013
(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
Interest rate derivative instruments	$	12,349		$	—		$	12,349		$	13,223		$	—		$	13,223

Total derivative liabilities	$	12,349		$	—		$	12,349		$	13,223		$	—		$	13,223




Puget Energy and	Fair Value									Fair Value
Puget Sound Energy	At June 30, 2014									At December 31, 2013
(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
Assets:
Electric derivative instruments	$	15,882		$	11,020		$	26,902		$	14,661		$	3,818		$	18,479

Natural gas derivative instruments	22,356			2,825			25,181			5,448			2,673			8,121

Total assets	$	38,238		$	13,845		$	52,083		$	20,109		$	6,491		$	26,600

Liabilities:

Electric derivative instruments	$	4,554		$	15,713		$	20,267		$	18,073		$	19,239		$	37,312

Natural gas derivative instruments	9,737			3,098			12,835			32,642			3,034			35,676

Total liabilities	$	14,291		$	18,811		$	33,102		$	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 June 30,
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	$	(14,606	)	$	(1,103	)	$	(15,709	)	$	(26,442	)	$	(1,534	)	$	(27,976	)
Changes during period:
Realized and unrealized energy derivatives:
Included in earnings 1	7,800			—			7,800			(12,799		)	—			(12,799		)

Included in regulatory assets / liabilities	—			2,120			2,120			—			(684		)	(684		)

Settlements 3	1,757			(166		)	1,591			2,678			(495		)	2,183

Transferred into Level 3	—			—			—			(830		)	—			(830		)

Transferred out of Level 3	356			(1,124		)	(768		)	494			(160		)	334

Balance at end of period	$	(4,693	)	$	(273	)	$	(4,966	)	$	(36,899	)	$	(2,873	)	$	(39,772	)



Puget Energy and	Six Months Ended
Puget Sound Energy	June 30,
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 2	5,055			—			5,055			(11,201		)	—			(11,201		)

Included in regulatory assets / liabilities	—			2,379			2,379			—			(10		)	(10		)

Settlements 3	2,078			(576		)	1,502			9,062			(1,228		)	7,834

Transferred into Level 3	3,100			(585		)	2,515			(8,530		)	—			(8,530		)

Transferred out of Level 3	495			(1,130		)	(635		)	7,694			(33		)	7,661

Balance at end of period	$	(4,693	)	$	(273	)	$	(4,966	)	$	(36,899	)	$	(2,873	)	$	(39,772	)
__________

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 $4.7 million and $(15.6) million for the three months ended June 30, 2014 and 2013, respectively.

2	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 $0.1 million and $(14.2) million for the six months ended June 30, 2014 and 2013, respectively.

3	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 June 30, 2014:



	Fair Value								Range
(Dollars in Thousands)	Assets 1			Liabilities 1			Valuation Technique	Unobservable Input	Low	High	Weighted Average
Electric	$	11,020		$	15,713		Discounted cash flow	Power Prices	$19.08 per MWh	$44.36 per MWh	$35.77 per MWh

Natural gas	$	2,825		$	3,098		Discounted cash flow	Natural Gas Prices	$3.84 per MMBtu	$4.09 per MMBtu	$4.02 per MMBtu

__________

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

Below are the forward price ranges for the Company's purchased commodity contracts, as of December 31, 2013:



	Fair Value								Range
(Dollars in Thousands)	Assets 1			Liabilities 1			Valuation Technique	Unobservable Input	Low	High	Weighted Average
Electric	$	3,818		$	19,239		Discounted cash flow	Power Prices	$17.06 per MWh	$47.09 per MWh	$38.74 per MWh

Natural gas	$	2,673		$	3,034		Discounted cash flow	Natural Gas Prices	$3.62 per MMBtu	$4.19 per MMBtu	$3.78 per MMBtu

_______________

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

The significant unobservable inputs listed above would have a direct impact on the fair values of the above instruments if they were adjusted. Consequently significant increases or decreases in the forward prices of electricity or natural gas in isolation would result in a significantly higher or lower fair value for Level 3 assets and liabilities. Generally, interrelationships exist between market prices of natural gas and power. As such, an increase in natural gas pricing would potentially have a similar impact on forward power markets. At June 30, 2014 and December 31, 2013, a hypothetical 10% increase or decrease in market prices of natural gas and electricity would change the fair value of the Company's derivative portfolio, classified as Level 3 within the fair value hierarchy, by $8.7 million and $7.0 million, respectively.

Retirement_Benefits

Retirement Benefits	6 Months Ended
	Jun. 30, 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. PSE also maintains a non-qualified Supplemental Executive Retirement Plan (SERP) for its key senior management employees.
	In addition to providing pension benefits, PSE provides group health care and life insurance benefits for certain retired 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 and six months ended June 30, 2014 and 2013:


	Puget Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
		Three Months Ended June 30,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:
	Service cost	$	4,206		$	4,934		$	261		$	375		$	26		$	32

	Interest cost	6,965			6,182			577			511			159			155

	Expected return on plan assets	(10,511		)	(9,696		)	—			—			(134		)	(109		)

	Amortization of prior service	(495		)	(495		)	11			(4		)	—			—
	cost
	Amortization of net loss	—			794			228			365			(130		)	18
	(gain)
	Net periodic benefit cost	$	165		$	1,719		$	1,077		$	1,247		$	(79	)	$	96





	Puget Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
		Six Months Ended
		June 30,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:
	Service cost	$	8,718		$	9,643		$	521		$	749		$	56		$	67

	Interest cost	14,020			12,377			1,155			1,022			342			332

	Expected return on plan assets	(21,232		)	(19,548		)	—			—			(267		)	(218		)

	Amortization of prior service	(990		)	(990		)	22			(9		)	(197		)	—
	cost
	Amortization of net loss	—			1,444			456			731			—			34
	(gain)
	Net periodic benefit cost	$	516		$	2,926		$	2,154		$	2,493		$	(66	)	$	215




	Puget Sound Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
		Three Months Ended June 30,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:

	Service cost	$	4,206		$	4,934		$	261		$	375		$	26		$	32

	Interest cost	6,965			6,182			577			511			159			155

	Expected return on plan assets	(10,708		)	(10,094		)	—			—			(134		)	(109		)

Amortization of prior service	(393		)	(393		)	11			(4		)	1			8
cost
Amortization of net loss	3,359			5,221			365			548			(208		)	(108		)
(gain)
Net periodic benefit cost	$	3,429		$	5,850		$	1,214		$	1,430		$	(156	)	$	(22	)




Puget Sound Energy	Qualified						SERP						Other
	Pension Benefits						Pension Benefits						Benefits
	Six Months Ended
	June 30,
(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
Components of net periodic benefit cost:
Service cost	$	8,718		$	9,643		$	521		$	749		$	56		$	67

Interest cost	14,020			12,377			1,155			1,022			342			332

Expected return on plan assets	(21,626		)	(20,343		)	—			—			(267		)	(218		)

Amortization of prior service	(786		)	(787		)	22			(8		)	2			14
cost
Amortization of net loss	6,597			10,306			730			1,096			(352		)	(142		)
(gain)
Net periodic benefit cost	$	6,923		$	11,196		$	2,428		$	2,859		$	(219	)	$	53



The following table summarizes the Company’s change in benefit obligation for the periods ended June 30, 2014 and December 31, 2013:



Puget Energy and	Qualified						SERP						Other
Puget Sound Energy	Pension Benefits						Pension Benefits						Benefits
	Six Months Ended			Year			Six Months Ended			Year			Six Months Ended			Year
				Ended						Ended						Ended
(Dollars in Thousands)	June 30,			December 31,			June 30,			December 31,			June 30,			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	8,718			19,285			521			1,498			56			134

Interest cost	14,020			24,754			1,155			2,045			342			664

Amendment	—			—			—			478			—			—

Actuarial Net loss/(gain)	1,878			(48,559		)	—			(1,687		)	(932		)	(2,240		)
BOY Census,
remeasurement
Benefits paid	(25,408		)	(38,453		)	(942		)	(6,850		)	(739		)	(1,536		)
Medicare part D subsidy	—			—			—						117			245
received
Benefit obligation at end of period	$	572,525		$	573,317		$	48,013		$	47,279		$	13,783		$	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 $0.3 million, respectively. During the three months ended June 30, 2014, the Company contributed $3.0 million, $0.5 million, and $0.1 million to fund the qualified pension plan, SERP and the other postretirement plan, respectively. During the six months ended June 30, 2014, the Company contributed $6.0 million, $0.9 million, and $0.3 million to fund the qualified pension plan, SERP and the other postretirement plan, respectively.

Regulation_and_Rates

Regulation and Rates	6 Months Ended
Regulation and Rates	Jun. 30, 2014
Regulation and Rates [Abstract]	'
Regulation and Rates	'
	Regulation and Rates
	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 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.
	On April 24, 2014, the Washington Commission also approved PSE’s request to change rates under its electric and natural gas conservation riders, effective May 1, 2014. The rate change incorporated the effects of changes in the annual conservation budgets as well as true-ups to the rate from the prior year. The rate change represents a rate increase for electric of $12.2 million, or 0.5% annually, and a rate increase for natural gas of $0.3 million.
	On May 23, 2014, PSE filed its 2014 power cost only rate case (PCORC). The filing proposes a decrease of $9.6 million (or an average of approximately 0.5%) in the Company's overall power supply costs with an effective date of December 1, 2014.
	On May 30, 2014, PSE filed a rate change under its natural gas cost recovery mechanism (CRM). The purpose of the CRM filing was to submit a tariff filing to recover the incremental cost of investments made under PSE’s approved Pipeline Replacement Program Plan (PRPP). This filing will be subsequently updated for actual investments to coincide with the requested recovery period of November 1, 2013, through October 31, 2014.
	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 were held on May 9, 2014. On June 25, 2014, the court issued a letter decision in which it affirmed the attrition adjustment (escalating factors referred to as the K-Factor) and the Washington Commission's decision not to consider the case as a general rate case, but reversed and remanded the cost of equity for further adjudication consistent with the court's decision.
	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.

Litigation

Litigation	6 Months Ended
Litigation	Jun. 30, 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 are pursuing certain claims relating to the amount of REP benefits paid to utilities, including PSE, for the period of fiscal years 2002 through 2011. 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 during the period June 1, 2014 to May 31, 2015.

	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 $1.29 million and $1.38 million relating to these claims as of June 30, 2014 and December 31, 2013, respectively.

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Income (Notes)	6 Months Ended
	Jun. 30, 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 and six months ended June 30, 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 March 31, 2014	$	48,305		$	(358	)	$	—		$	47,947

	Other comprehensive income (loss) before reclassifications	(615		)	—			—			(615		)

	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	(168		)	—			—			(168		)

	Net current-period other comprehensive income (loss)	(783		)	—			—			(783		)

	Balance at June 30, 2014	$	47,522		$	(358	)	$	—		$	47,164




	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	(615		)	—			—			(615		)

	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	(377		)	347			94			64

	Net current-period other comprehensive income (loss)	(992		)	347			94			(551		)

	Balance at June 30, 2014	$	47,522		$	(358	)	$	—		$	47,164




	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 March 31, 2014	$	(85,404	)	$	(1,309	)	$	(6,228	)	$	(92,941	)
	Other comprehensive income (loss) before reclassifications	(615		)	—			—			(615		)

	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	2,039			—			79			2,118

	Net current-period other comprehensive income (loss)	1,424			—			79			1,503

	Balance at June 30, 2014	$	(83,980	)	$	(1,309	)	$	(6,149	)	$	(91,438	)



	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	(615		)	—			—			(615		)

	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	4,040			718			158			4,916

	Net current-period other comprehensive income (loss)	3,425			718			158			4,301

Balance at June 30, 2014	$	(83,980	)	$	(1,309	)	$	(6,149	)	$	(91,438	)

Details about these reclassifications out of accumulated other comprehensive income (loss) for the three and six months ended June 30, 2014 and three and six months ended June 30, 2013, respectively, are as follows:


Puget Energy		Three Months Ended June 30,						Six Months Ended
								June 30,
(Dollars in Thousands)		2014			2013			2014			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		$	1,165		$	999

Amortization of net gain (loss)	(a)	(98		)	(1,177		)	(456		)	(2,209		)
	Total before tax	386			(678		)	709			(1,210		)

	Tax (expense) or benefit	(135		)	237			(248		)	422

	Net of Tax	$	251		$	(441	)	$	461		$	(788	)

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	—			(1,325		)	(144		)	(2,639		)

	Tax (expense) or benefit	—			464			50			924

	Net of Tax	$	—		$	(861	)	$	(94	)	$	(1,715	)

Total reclassification for the period	Net of Tax	$	251		$	(1,302	)	$	20		$	(2,396	)

__________

(a)	These accumulated OCI components are included in the computation of net periodic pension cost (see Note 5 for additional details).


Puget Sound Energy		Three Months Ended June 30,						Six Months Ended
								June 30,
(Dollars in Thousands)		2014			2013			2014			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		$	762		$	781

Amortization of net gain (loss)	(a)	(3,516		)	(5,661		)	(6,975		)	(11,260		)
	Total before tax	(3,135		)	(5,272		)	(6,213		)	(10,479		)
	Tax (expense) or benefit	1,097			1,845			2,175			3,666

	Net of Tax	$	(2,038	)	$	(3,427	)	$	(4,038	)	$	(6,813	)
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		)	(244		)	(244		)
	Tax (expense) or benefit	43			43			86			86

	Net of Tax	$	(79	)	$	(79	)	$	(158	)	$	(158	)
Total reclassification for the period	Net of Tax	$	(2,117	)	$	(3,506	)	$	(4,914	)	$	(8,782	)
__________

(a)	These accumulated OCI components are included in the computation of net periodic pension cost (see Note 5 for additional details).

Other

Other	6 Months Ended
Other	Jun. 30, 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 maintain such separate accounts and accounting entries as are necessary to preserve fully the Washington Commission’s opportunity to consider in an appropriate proceeding the disposition of proceeds of sale and rate treatment of this transaction. 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 authorizing PSE to retain $45.0 million of the gain and to 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. PSE filed rebuttal testimony and intervenors filed cross-answering testimony on April 22, 2014. The Washington Commission held evidentiary hearings in this matter on May 21, 2014. Initial legal briefs were filed on June 10, 2014 and reply briefs were filed on June 17, 2014. A final order is anticipated in the third quarter of this year.
	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.
	Credit Facilities
	In April 2014, subsequent to the close of the first quarter, the Company completed a one-year extension on the liquidity and hedging facilities of PSE, extending the maturity from February 2018 to April 2019 and updating or clarifying the definitions of other terms and conditions of the facilities from when they were committed in 2013. At this same time, the Company completed an amendment to the senior secured credit facility of Puget Energy, extending the maturity from February 2017 to April 2018, updating the fee structure, eliminating a financial covenant and updating or clarifying the definitions of other terms and conditions of the facility.

	Term Loans
	In June 2014, Puget Energy entered into three bilateral term loans, with two and three year maturities, which in total, equal $299.0 million . The proceeds of these term loans were used to pay off the outstanding Puget Energy credit facility balance, which subsequently allows the Company to carry the debt with lower interest expense. The terms, conditions and covenants are consistent with each other and the credit facility agreements, with the exception of maturity and price.

	Treasury Grants
	PSE received two treasury grants in the amount of $107.8 million, related to Baker and Snoqualmie hydro facilities. These grants have been accounted as a reduction to utility plant and will be amortized over the life of the plant based on Washington Commission authorization. The previous treatment of grants by the Washington Commission is to amortize the grants over 10 years instead of the plant life. The grants are also recorded as a regulatory liability due to the 10 year amortization and treatment.

Summary_of_Significant_Account

Summary of Significant Accounting Policies (Policies)	6 Months Ended
Summary of Significant Accounting Policies (Policies)	Jun. 30, 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 Western, Inc. 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 $50.6 million and $128.5 million for the three and six months ended June 30, 2014, respectively, and $51.5 million and $128.4 million for the three and six months ended June 30, 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.
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 Western, Inc. 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 $50.6 million and $128.5 million for the three and six months ended June 30, 2014, respectively, and $51.5 million and $128.4 million for the three and six months ended June 30, 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.

Accounting_for_Derivative_Inst1

Accounting for Derivative Instruments and Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 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	June 30, 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	$	—		$	12,349		$450 million	$	—		$	13,223

	Electric portfolio derivatives	*	26,902			20,266			*	18,479			37,312

	Natural gas derivatives (MMBtus) 4	359.0 million	25,181			12,836			423.5 million	8,121			35,676

	Total derivative contracts		$	52,083		$	45,451			$	26,600		$	86,211

	Current		$	44,405		$	23,690			$	18,867		$	48,049

	Long-term		7,678			21,761				7,733			38,162

	Total derivative contracts		$	52,083		$	45,451			$	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 139.8 million One Million British Thermal Units (MMBtus) and purchased electricity of 5.5 million Megawatt Hours (MWhs) at June 30, 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
	June 30, 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	$	52,083		—			$	52,083		$	(22,446	)	$	—	$	29,637

	Liabilities
	Energy Derivative Contracts	$	33,102		$	—		$	33,102		$	(22,446	)	$	43	$	10,699

	Interest Rate Swaps 2	$	12,349		$	—		$	12,349		$	—		$	—	$	12,349


	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 June 30, 2014:



	Puget Energy and Puget Sound Energy	Fair Value 1			Posted			Contingent
	Contingent Feature
	(Dollars in Thousands)	Liability			Collateral			Collateral
	Credit rating 2	$	(6,909	)	$	—		$	6,909

	Requested credit for adequate assurance	(10,207		)	—			—

	Forward value of contract 3	(43		)	43			—

	Total	$	(17,159	)	$	43		$	6,909

	__________

	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.
Parent Company [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 June 30,						Six Months Ended
									June 30,
	(Dollars in Thousands)	Location	2014			2013			2014			2013
	Interest rate contracts:	Non-hedged interest rate swap	$	(1,360	)	$	1,232		$	(2,107	)	$	2,260
		(expense) income
		Interest expense	(718		)	1,902			(843		)	(676		)

	Commodity contracts:

	Electric derivatives	Unrealized gain (loss) on derivative instruments, net	17,094			(27,376		)	24,934			48,316

		Electric generation fuel	864			(930		)	8,691			(13,568		)

		Purchased electricity	(3,668		)	(3,704		)	1,715			(35,189		)

	Total gain (loss) recognized in income on derivatives		$	12,212		$	(28,876	)	$	32,390		$	1,143

Subsidiaries [Member]	'
Derivative [Line Items]	'
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	'


	Puget Sound Energy		Three Months Ended June 30,						Six Months Ended
									June 30,
	(Dollars in Thousands)	Location	2014			2013			2014			2013
	Commodity contracts:
	Electric derivatives	Unrealized gain (loss) on derivative instruments, net	$	17,094		$	(27,376	)	$	24,364		$	45,365

		Electric generation fuel	864			(930		)	8,691			(13,568		)

		Purchased electricity	(3,668		)	(3,704		)	1,715			(35,189		)

	Total gain (loss) recognized in income on derivatives		$	14,290		$	(32,010	)	$	34,770		$	(3,392	)

Schedule of Derivative Instruments, Effect on Other Comprehensive Income (Loss)	'




	Puget Sound Energy		Three Months Ended June 30,						Six Months Ended
									June 30,
	(Dollars in Thousands)	Location	2014			2013			2014			2013
	Interest rate contracts:	Interest expense	$	(122	)	$	(122	)	$	(244	)	$	(244	)
	Commodity contracts:
	Electric derivatives	Electric generation fuel	—			—			—			—

		Purchased electricity	—			—			(1,104		)	(2,786		)

	Total		$	(122	)	$	(122	)	$	(1,348	)	$	(3,030	)
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 June 30,						Six Months Ended
									June 30,
	(Dollars in Thousands)	Location	2014			2013			2014			2013
	Interest rate contracts:	Interest expense	$	—		$	(1,325	)	$	(144	)	$	(2,639	)

	Commodity contracts:
	Electric derivatives	Electric generation fuel	—			—			—			—

		Purchased electricity	—			—			(534		)	164

	Total		$	—		$	(1,325	)	$	(678	)	$	(2,475	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 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 June 30, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	84,707		$	—		$	84,707		$	44,302		$	—		$	44,302

	Restricted Cash	54,964			—			54,964			7,171			—			7,171

	Notes Receivable and Other	—			52,692			52,692			—			53,449			53,449

	Total assets	$	139,671		$	52,692		$	192,363		$	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 June 30, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 1			Level 2			Total			Level 1			Level 2			Total
	Assets:
	Cash and Cash Equivalents	$	69,160		$	—		$	69,160		$	44,111		$	—		$	44,111

	Restricted Cash	54,964			—			54,964			7,171			—			7,171

	Notes Receivable and Other	—			52,692			52,692			—			53,449			53,449

	Total assets	$	124,124		$	52,692		$	176,816		$	51,282		$	53,449		$	104,731

	Liabilities:
	Short-term debt	$	—		$	—		$	—		$	162,000		$	—		$	162,000

	Short-term debt owed to parent	—			28,933			28,933			—			29,598			29,598

	Total liabilities	$	—		$	28,933		$	28,933		$	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		June 30, 2014						December 31, 2013
	(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value
	Liabilities:
	Junior subordinated notes	2	$	250,000		$	296,696		$	250,000		$	269,366

	Long-term debt (fixed-rate), net of discount	2	4,689,042			6,018,770			4,683,476			5,594,314

	Long-term debt (variable-rate)	2	299,000			299,000			299,000			299,000

	Total		$	5,238,042		$	6,614,466		$	5,232,476		$	6,162,680


	Puget Sound Energy		June 30, 2014						December 31, 2013
	(Dollars in Thousands)	Level	Carrying			Fair			Carrying			Fair
			Value			Value			Value			Value
	Liabilities:
	Junior subordinated notes	2	$	250,000		$	296,696		$	250,000		$	269,366

	Long-term debt (fixed-rate), net of discount	2	3,513,258			4,352,590			3,513,258			4,038,455

	Total		$	3,763,258		$	4,649,286		$	3,763,258		$	4,307,821

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	'



	Puget Energy and	Three Months Ended June 30,
	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	$	(14,606	)	$	(1,103	)	$	(15,709	)	$	(26,442	)	$	(1,534	)	$	(27,976	)
	Changes during period:
	Realized and unrealized energy derivatives:
	Included in earnings 1	7,800			—			7,800			(12,799		)	—			(12,799		)

	Included in regulatory assets / liabilities	—			2,120			2,120			—			(684		)	(684		)

	Settlements 3	1,757			(166		)	1,591			2,678			(495		)	2,183

	Transferred into Level 3	—			—			—			(830		)	—			(830		)

	Transferred out of Level 3	356			(1,124		)	(768		)	494			(160		)	334

	Balance at end of period	$	(4,693	)	$	(273	)	$	(4,966	)	$	(36,899	)	$	(2,873	)	$	(39,772	)



	Puget Energy and	Six Months Ended
	Puget Sound Energy	June 30,
	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 2	5,055			—			5,055			(11,201		)	—			(11,201		)

	Included in regulatory assets / liabilities	—			2,379			2,379			—			(10		)	(10		)

	Settlements 3	2,078			(576		)	1,502			9,062			(1,228		)	7,834

	Transferred into Level 3	3,100			(585		)	2,515			(8,530		)	—			(8,530		)

	Transferred out of Level 3	495			(1,130		)	(635		)	7,694			(33		)	7,661

	Balance at end of period	$	(4,693	)	$	(273	)	$	(4,966	)	$	(36,899	)	$	(2,873	)	$	(39,772	)
	__________

	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 $4.7 million and $(15.6) million for the three months ended June 30, 2014 and 2013, respectively.

	2	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 $0.1 million and $(14.2) million for the six months ended June 30, 2014 and 2013, respectively.

	3	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 June 30, 2014:



		Fair Value								Range
	(Dollars in Thousands)	Assets 1			Liabilities 1			Valuation Technique	Unobservable Input	Low	High	Weighted Average
	Electric	$	11,020		$	15,713		Discounted cash flow	Power Prices	$19.08 per MWh	$44.36 per MWh	$35.77 per MWh

	Natural gas	$	2,825		$	3,098		Discounted cash flow	Natural Gas Prices	$3.84 per MMBtu	$4.09 per MMBtu	$4.02 per MMBtu

	__________

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

	Below are the forward price ranges for the Company's purchased commodity contracts, as of December 31, 2013:



		Fair Value								Range
	(Dollars in Thousands)	Assets 1			Liabilities 1			Valuation Technique	Unobservable Input	Low	High	Weighted Average
	Electric	$	3,818		$	19,239		Discounted cash flow	Power Prices	$17.06 per MWh	$47.09 per MWh	$38.74 per MWh

	Natural gas	$	2,673		$	3,034		Discounted cash flow	Natural Gas Prices	$3.62 per MMBtu	$4.19 per MMBtu	$3.78 per MMBtu

	_______________

	1	The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions.
Parent Company [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 June 30, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
	Interest rate derivative instruments	$	12,349		$	—		$	12,349		$	13,223		$	—		$	13,223

	Total derivative liabilities	$	12,349		$	—		$	12,349		$	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 June 30, 2014									At December 31, 2013
	(Dollars in Thousands)	Level 2			Level 3			Total			Level 2			Level 3			Total
	Assets:
	Electric derivative instruments	$	15,882		$	11,020		$	26,902		$	14,661		$	3,818		$	18,479

	Natural gas derivative instruments	22,356			2,825			25,181			5,448			2,673			8,121

	Total assets	$	38,238		$	13,845		$	52,083		$	20,109		$	6,491		$	26,600

	Liabilities:

	Electric derivative instruments	$	4,554		$	15,713		$	20,267		$	18,073		$	19,239		$	37,312

	Natural gas derivative instruments	9,737			3,098			12,835			32,642			3,034			35,676

	Total liabilities	$	14,291		$	18,811		$	33,102		$	50,715		$	22,273		$	72,988

Retirement_Benefits_Tables

Retirement Benefits (Tables)	6 Months Ended
	Jun. 30, 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 June 30, 2014 and December 31, 2013:



	Puget Energy and	Qualified						SERP						Other
	Puget Sound Energy	Pension Benefits						Pension Benefits						Benefits
		Six Months Ended			Year			Six Months Ended			Year			Six Months Ended			Year
					Ended						Ended						Ended
	(Dollars in Thousands)	June 30,			December 31,			June 30,			December 31,			June 30,			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	8,718			19,285			521			1,498			56			134

	Interest cost	14,020			24,754			1,155			2,045			342			664

	Amendment	—			—			—			478			—			—

	Actuarial Net loss/(gain)	1,878			(48,559		)	—			(1,687		)	(932		)	(2,240		)
	BOY Census,
	remeasurement
	Benefits paid	(25,408		)	(38,453		)	(942		)	(6,850		)	(739		)	(1,536		)
	Medicare part D subsidy	—			—			—						117			245
	received
	Benefit obligation at end of period	$	572,525		$	573,317		$	48,013		$	47,279		$	13,783		$	14,939

Parent Company [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 and six months ended June 30, 2014 and 2013:


	Puget Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
		Three Months Ended June 30,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:
	Service cost	$	4,206		$	4,934		$	261		$	375		$	26		$	32

	Interest cost	6,965			6,182			577			511			159			155

	Expected return on plan assets	(10,511		)	(9,696		)	—			—			(134		)	(109		)

	Amortization of prior service	(495		)	(495		)	11			(4		)	—			—
	cost
	Amortization of net loss	—			794			228			365			(130		)	18
	(gain)
	Net periodic benefit cost	$	165		$	1,719		$	1,077		$	1,247		$	(79	)	$	96





	Puget Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
		Six Months Ended
		June 30,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:
	Service cost	$	8,718		$	9,643		$	521		$	749		$	56		$	67

	Interest cost	14,020			12,377			1,155			1,022			342			332

	Expected return on plan assets	(21,232		)	(19,548		)	—			—			(267		)	(218		)

	Amortization of prior service	(990		)	(990		)	22			(9		)	(197		)	—
	cost
	Amortization of net loss	—			1,444			456			731			—			34
	(gain)
	Net periodic benefit cost	$	516		$	2,926		$	2,154		$	2,493		$	(66	)	$	215

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 June 30,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:

	Service cost	$	4,206		$	4,934		$	261		$	375		$	26		$	32

	Interest cost	6,965			6,182			577			511			159			155

	Expected return on plan assets	(10,708		)	(10,094		)	—			—			(134		)	(109		)

	Amortization of prior service	(393		)	(393		)	11			(4		)	1			8
	cost
	Amortization of net loss	3,359			5,221			365			548			(208		)	(108		)
	(gain)
	Net periodic benefit cost	$	3,429		$	5,850		$	1,214		$	1,430		$	(156	)	$	(22	)




	Puget Sound Energy	Qualified						SERP						Other
		Pension Benefits						Pension Benefits						Benefits
		Six Months Ended
		June 30,
	(Dollars in Thousands)	2014			2013			2014			2013			2014			2013
	Components of net periodic benefit cost:
	Service cost	$	8,718		$	9,643		$	521		$	749		$	56		$	67

	Interest cost	14,020			12,377			1,155			1,022			342			332

	Expected return on plan assets	(21,626		)	(20,343		)	—			—			(267		)	(218		)

	Amortization of prior service	(786		)	(787		)	22			(8		)	2			14
	cost
	Amortization of net loss	6,597			10,306			730			1,096			(352		)	(142		)
	(gain)
	Net periodic benefit cost	$	6,923		$	11,196		$	2,428		$	2,859		$	(219	)	$	53

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Income (Tables)	6 Months Ended
	Jun. 30, 2014
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 and six months ended June 30, 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 March 31, 2014	$	48,305		$	(358	)	$	—		$	47,947

	Other comprehensive income (loss) before reclassifications	(615		)	—			—			(615		)

	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	(168		)	—			—			(168		)

	Net current-period other comprehensive income (loss)	(783		)	—			—			(783		)

	Balance at June 30, 2014	$	47,522		$	(358	)	$	—		$	47,164




	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	(615		)	—			—			(615		)

	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	(377		)	347			94			64

	Net current-period other comprehensive income (loss)	(992		)	347			94			(551		)

	Balance at June 30, 2014	$	47,522		$	(358	)	$	—		$	47,164

Parent Company [Member]	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Reclassification out of Accumulated Other Comprehensive Income	'

	Details about these reclassifications out of accumulated other comprehensive income (loss) for the three and six months ended June 30, 2014 and three and six months ended June 30, 2013, respectively, are as follows:


	Puget Energy		Three Months Ended June 30,						Six Months Ended
									June 30,
	(Dollars in Thousands)		2014			2013			2014			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		$	1,165		$	999

	Amortization of net gain (loss)	(a)	(98		)	(1,177		)	(456		)	(2,209		)
		Total before tax	386			(678		)	709			(1,210		)

		Tax (expense) or benefit	(135		)	237			(248		)	422

		Net of Tax	$	251		$	(441	)	$	461		$	(788	)

	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	—			(1,325		)	(144		)	(2,639		)

		Tax (expense) or benefit	—			464			50			924

		Net of Tax	$	—		$	(861	)	$	(94	)	$	(1,715	)

	Total reclassification for the period	Net of Tax	$	251		$	(1,302	)	$	20		$	(2,396	)

	__________

	(a)	These accumulated OCI components are included in the computation of net periodic pension cost (see Note 5 for additional details).
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 March 31, 2014	$	(85,404	)	$	(1,309	)	$	(6,228	)	$	(92,941	)
	Other comprehensive income (loss) before reclassifications	(615		)	—			—			(615		)

	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	2,039			—			79			2,118

	Net current-period other comprehensive income (loss)	1,424			—			79			1,503

	Balance at June 30, 2014	$	(83,980	)	$	(1,309	)	$	(6,149	)	$	(91,438	)



	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	(615		)	—			—			(615		)

	Amounts reclassified from accumulated other comprehensive income (loss), net of tax	4,040			718			158			4,916

	Net current-period other comprehensive income (loss)	3,425			718			158			4,301

	Balance at June 30, 2014	$	(83,980	)	$	(1,309	)	$	(6,149	)	$	(91,438	)
Reclassification out of Accumulated Other Comprehensive Income	'


	Puget Sound Energy		Three Months Ended June 30,						Six Months Ended
									June 30,
	(Dollars in Thousands)		2014			2013			2014			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		$	762		$	781

	Amortization of net gain (loss)	(a)	(3,516		)	(5,661		)	(6,975		)	(11,260		)
		Total before tax	(3,135		)	(5,272		)	(6,213		)	(10,479		)
		Tax (expense) or benefit	1,097			1,845			2,175			3,666

		Net of Tax	$	(2,038	)	$	(3,427	)	$	(4,038	)	$	(6,813	)
	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		)	(244		)	(244		)
		Tax (expense) or benefit	43			43			86			86

		Net of Tax	$	(79	)	$	(79	)	$	(158	)	$	(158	)
	Total reclassification for the period	Net of Tax	$	(2,117	)	$	(3,506	)	$	(4,914	)	$	(8,782	)
	__________

	(a)	These accumulated OCI components are included in the computation of net periodic pension cost (see Note 5 for additional details).

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Details) (Subsidiaries [Member], USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
	sqmi	Jun. 30, 2013	sqmi	Jun. 30, 2013
Subsidiaries [Member]	'	'	'	'
Schedule of Capitalization, Equity [Line Items]	'	'	'	'
Area of Service Territory (in sqmi)	6,000	'	6,000	'
Excise taxes collected	$50.60	$51.50	$128.50	$128.40

Accounting_for_Derivative_Inst2

Accounting for Derivative Instruments and Hedging Activities Derivative Activity and Notional Amounts (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013
In Millions, unless otherwise specified	Jun. 30, 2014		Dec. 31, 2013
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	359,000,000	[2]	423,500,000	[2]
Electric generation fuel [Member] \| Not Designated as Hedging Instrument [Member]	'		'
Derivative [Line Items]	'		'
Derivative, Notional amount, Nonmonetary	139,800,000		145,600,000
Purchased Electricity [Member] \| Not Designated as Hedging Instrument [Member]	'		'
Derivative [Line Items]	'		'
Derivative, Notional amount, Nonmonetary	5,500,000		8,600,000
Parent Company [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 $)	Jun. 30, 2014		Dec. 31, 2013
Derivative [Line Items]	'		'
Unrealized gain on derivative instruments	$44,405,000		$18,867,000
Assets, Long-term	7,678,000		7,733,000
Unrealized loss on derivative instruments	23,690,000		48,049,000
Unrealized loss on derivative instruments	21,761,000		38,162,000
Subsidiaries [Member]	'		'
Derivative [Line Items]	'		'
Unrealized gain on derivative instruments	44,405,000		18,867,000
Assets, Long-term	7,678,000		7,733,000
Unrealized loss on derivative instruments	16,895,000		41,465,000
Unrealized loss on derivative instruments	16,208,000		31,523,000
Commodity Contract [Member]	'		'
Derivative [Line Items]	'		'
Assets	52,083,000		26,600,000
Derivative Liability	33,102,000		72,988,000
Not Designated as Hedging Instrument [Member]	'		'
Derivative [Line Items]	'		'
Assets	52,083,000	[1]	26,600,000	[1]
Derivative Liability	45,451,000	[2]	86,211,000	[2]
Not Designated as Hedging Instrument [Member] \| Parent Company [Member]	'		'
Derivative [Line Items]	'		'
Unrealized gain on derivative instruments	44,405,000	[1]	18,867,000	[1]
Assets, Long-term	7,678,000	[1]	7,733,000	[1]
Unrealized loss on derivative instruments	23,690,000	[2]	48,049,000	[2]
Unrealized loss on derivative instruments	21,761,000	[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]
Derivative Liability	12,349,000	[2],[3]	13,223,000	[2],[3]
Not Designated as Hedging Instrument [Member] \| Electric portfolio [Member]	'		'
Derivative [Line Items]	'		'
Assets	26,902,000	[1]	18,479,000	[1]
Derivative Liability	20,266,000	[2]	37,312,000	[2]
Not Designated as Hedging Instrument [Member] \| Natural gas portfolio [Member]	'		'
Derivative [Line Items]	'		'
Assets	25,181,000	[1],[4]	8,121,000	[1],[4]
Derivative Liability	$12,836,000	[2],[4]	$35,676,000	[2],[4]
Not Designated as Hedging Instrument [Member] \| Natural Gas Derivatives [Member]	'		'
Derivative [Line Items]	'		'
Derivative, Nonmonetary Notional Amount	359,000,000	[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 $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014		Dec. 31, 2013		Jun. 30, 2014		Dec. 31, 2013
	Jun. 30, 2014	Jun. 30, 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)	($26,013)	'		'		'		'
Assets	'	'	'		'		'		'
Gross Amount Recognized in the Statement of Financial Position	'	'	52,083	[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	'	'	52,083		26,600		'		'
Commodity Contracts	'	'	-22,446		-19,491		'		'
Cash Collateral Received	'	'	0		0		'		'
Net Amount	'	'	29,637		7,109		'		'
Liabilities	'	'	'		'		'		'
Gross Amount Recognized in the Statement of Financial Position	'	'	33,102	[1]	72,988	[1]	12,349	[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	'	'	33,102		72,988		12,349	[2]	13,223	[2]
Commodity Contracts	'	'	-22,446		-19,491		0	[2]	0	[2]
Cash Collateral Posted	'	'	43		0		0	[2]	0	[2]
Net Amount	'	'	$10,699		$53,497		$12,349	[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		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Derivative Instruments, (Loss) Gain [Line Items]	'	'	'	'
Purchased electricity	$114,627	$112,543	$295,785	$287,587
Unrealized (gain) loss on derivative instruments	-17,094	27,376	-24,934	-48,316
Subsidiaries [Member]	'	'	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'	'	'
Purchased electricity	114,627	112,543	295,785	287,587
Unrealized (gain) loss on derivative instruments	-17,094	27,376	-24,364	-45,365
Not Designated as Hedging Instrument [Member] \| Parent Company [Member]	'	'	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'	'	'
Unrealized (gain) loss on derivative instruments	-12,212	28,876	-32,390	-1,143
Not Designated as Hedging Instrument [Member] \| Parent Company [Member] \| Other Income (Deductions) [Member] \| Interest Expense [Member]	'	'	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'	'	'
Unrealized (gain) loss on derivative instruments	1,360	-1,232	2,107	-2,260
Not Designated as Hedging Instrument [Member] \| Parent Company [Member] \| Interest Rate Contract [Member] \| Interest Expense [Member]	'	'	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'	'	'
Unrealized (gain) loss on derivative instruments	718	-1,902	843	676
Not Designated as Hedging Instrument [Member] \| Parent Company [Member] \| Commodity Contract [Member] \| Unrealized (Gain) Loss on Derivative Instruments, Net [Member]	'	'	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'	'	'
Unrealized (gain) loss on derivative instruments	-17,094	27,376	-24,934	-48,316
Not Designated as Hedging Instrument [Member] \| Parent Company [Member] \| Commodity Contract [Member] \| Electric generation fuel [Member]	'	'	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'	'	'
Unrealized (gain) loss on derivative instruments	-864	930	-8,691	13,568
Not Designated as Hedging Instrument [Member] \| Parent Company [Member] \| Commodity Contract [Member] \| Purchased Electricity [Member]	'	'	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'	'	'
Unrealized (gain) loss on derivative instruments	3,668	3,704	-1,715	35,189
Not Designated as Hedging Instrument [Member] \| Subsidiaries [Member]	'	'	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'	'	'
Unrealized (gain) loss on derivative instruments	-14,290	32,010	-34,770	3,392
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	-17,094	27,376	-24,364	-45,365
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	-864	930	-8,691	13,568
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	3,668	3,704	-1,715	35,189
Cash Flow Hedging [Member] \| Parent Company [Member]	'	'	'	'
Derivative Instruments, (Loss) Gain [Line Items]	'	'	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	-1,325	-678	-2,475
Cash Flow Hedging [Member] \| Parent Company [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	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	-122	-122	-1,348	-3,030
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	$0	$0

Accounting_for_Derivative_Inst6

Accounting for Derivative Instruments and Hedging Activities Recognized in Other Comprehensive Income (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Parent Company [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]	'	'	'	'
Cash Flow Hedge Loss to be Reclassified within Twelve Months	'	'	-2,000,000	'
Cash Flow Hedging [Member] \| Parent Company [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	-1,325,000	-678,000	-2,475,000
Cash Flow Hedging [Member] \| Parent Company [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	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	-122,000	-122,000	-1,348,000	-3,030,000
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	$0	$0

Accounting_for_Derivative_Inst7

Accounting for Derivative Instruments and Hedging Activities Contractual Contingent Liability (Details) (USD $)	Jun. 30, 2014
In Thousands, unless otherwise specified	Jun. 30, 2014
Electric portfolio [Member]	'
Derivative [Line Items]	'
Fair Value Liability	($17,159)	[1]
Posted Collateral	43
Additional Collateral, Aggregate Fair Value	6,909
Electric portfolio [Member] \| Credit Rating [Member]	'
Derivative [Line Items]	'
Fair Value Liability	-6,909	[1],[2]
Posted Collateral	0	[2]
Additional Collateral, Aggregate Fair Value	6,909	[2]
Electric portfolio [Member] \| Requested credit for adequate assurance [Member]	'
Derivative [Line Items]	'
Fair Value Liability	-10,207	[1]
Posted Collateral	0
Additional Collateral, Aggregate Fair Value	0
Electric portfolio [Member] \| Forward value of contract [Member]	'
Derivative [Line Items]	'
Fair Value Liability	-43	[1],[3]
Posted Collateral	43	[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 $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Parent Company [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	$84,707	$44,302
Restricted Cash	54,964	7,171
Notes Receivable and Other	52,692	53,449
Total assets	192,363	104,922
Liabilities:	'	'
Short-term Debt	0	162,000
Total liabilities	0	162,000
Parent Company [Member] \| Level 1 [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	84,707	44,302
Restricted Cash	54,964	7,171
Notes Receivable and Other	0	0
Total assets	139,671	51,473
Liabilities:	'	'
Short-term Debt	0	162,000
Total liabilities	0	162,000
Parent Company [Member] \| Level 2 [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	0	0
Restricted Cash	0	0
Notes Receivable and Other	52,692	53,449
Total assets	52,692	53,449
Liabilities:	'	'
Short-term Debt	0	0
Total liabilities	0	0
Subsidiaries [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	69,160	44,111
Restricted Cash	54,964	7,171
Notes Receivable and Other	52,692	53,449
Total assets	176,816	104,731
Liabilities:	'	'
Short-term Debt	0	162,000
Short-term Debt owed by PSE to PE	28,933	29,598
Total liabilities	28,933	191,598
Subsidiaries [Member] \| Level 1 [Member]	'	'
Assets:	'	'
Cash and Cash Equivalents	69,160	44,111
Restricted Cash	54,964	7,171
Notes Receivable and Other	0	0
Total assets	124,124	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	52,692	53,449
Total assets	52,692	53,449
Liabilities:	'	'
Short-term Debt	0	0
Short-term Debt owed by PSE to PE	28,933	29,598
Total liabilities	$28,933	$29,598

Fair_Value_Measurements_Debt_a

Fair Value Measurements Debt at at Carrying and Fair Value (Details) (Discounted cash flow [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Parent Company [Member] \| Carrying Value [Member]	'	'
Liabilities:	'	'
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	$5,238,042	$5,232,476
Parent Company [Member] \| Carrying Value [Member] \| Level 2 [Member]	'	'
Liabilities:	'	'
Junior subordinated notes	250,000	250,000
Long-term debt (fixed-rate), net of discount	4,689,042	4,683,476
Long Term Debt (variable rate) net of discount	299,000	299,000
Parent Company [Member] \| Fair Value [Member]	'	'
Liabilities:	'	'
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	6,614,466	6,162,680
Parent Company [Member] \| Fair Value [Member] \| Level 2 [Member]	'	'
Liabilities:	'	'
Junior subordinated notes	296,696	269,366
Long-term debt (fixed-rate), net of discount	6,018,770	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	4,649,286	4,307,821
Subsidiaries [Member] \| Fair Value [Member] \| Level 2 [Member]	'	'
Liabilities:	'	'
Junior subordinated notes	296,696	269,366
Long-term debt (fixed-rate), net of discount	$4,352,590	$4,038,455

Fair_Value_Measurements_Assets

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

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Electric portfolio [Member]

Natural gas portfolio [Member]

Commodity Contract [Member]

Interest Rate Contract [Member]

Fair Value, Measurements, Recurring [Member]

Parent Company [Member]

Subsidiaries [Member]

Level 2 [Member]

Level 3 [Member]

Total [Member]

Level 2 [Member]

Level 3 [Member]

Total [Member]

Interest Rate Contract [Member]

Commodity Contract [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

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

Unrealized Gain (Loss) on Derivatives and Commodity Contracts

$4,700,000

($15,600,000)

$100,000

($14,200,000)

Derivative Assets

52,083,000

26,600,000

38,238,000

20,109,000

15,882,000

14,661,000

22,356,000

5,448,000

13,845,000

6,491,000

11,020,000

[1]

3,818,000

[1]

2,825,000

[1]

2,673,000

[1]

52,083,000

26,600,000

26,902,000

18,479,000

25,181,000

8,121,000

Derivative Liability

33,102,000

72,988,000

12,349,000

[2]

13,223,000

[2]

12,349,000

13,223,000

12,349,000

13,223,000

12,349,000

13,223,000

12,349,000

13,223,000

14,291,000

50,715,000

4,554,000

18,073,000

9,737,000

32,642,000

18,811,000

22,273,000

15,713,000

[1]

19,239,000

[1]

3,098,000

[1]

3,034,000

[1]

33,102,000

72,988,000

20,267,000

37,312,000

12,835,000

35,676,000

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

Balance at beginning of period

-15,709,000

-27,976,000

-15,782,000

-35,526,000

-14,606,000

-26,442,000

-15,421,000

-33,924,000

-1,103,000

-1,534,000

-361,000

-1,602,000

Included in earnings

7,800,000

[3]

-12,799,000

[3]

5,055,000

[3]

-11,201,000

[3]

7,800,000

[3]

-12,799,000

[3]

5,055,000

[3]

-11,201,000

[3]

Included in regulatory assets/liabilities

2,120,000

-684,000

2,379,000

-10,000

2,120,000

-684,000

2,379,000

-10,000

Settlements

1,591,000

[4]

2,183,000

[4]

1,502,000

[4]

7,834,000

[4]

1,757,000

[4]

2,678,000

[4]

2,078,000

[4]

9,062,000

[4]

-166,000

[4]

-495,000

[4]

-576,000

[4]

-1,228,000

[4]

Transferred into Level 3

-830,000

2,515,000

-8,530,000

-830,000

3,100,000

-8,530,000

-585,000

Transferred out of Level 3

-768,000

334,000

-635,000

7,661,000

356,000

494,000

495,000

7,694,000

-1,124,000

-160,000

-1,130,000

-33,000

Balance at end of period

($4,966,000)

($39,772,000)

($4,966,000)

($39,772,000)

($4,693,000)

($36,899,000)

($4,693,000)

($36,899,000)

($273,000)

($2,873,000)

($273,000)

($2,873,000)

[1]

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

[2]

2B Interest Rate Swap Contracts are only held at Puget Energy.

[3]

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 $4.7 million and $(15.6) million for the three months ended JuneB 30, 2014 and 2013, respectively. 2B 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 $0.1 million and $(14.2) million for the six months ended JuneB 30, 2014 and 2013, respectively.

[4]

3 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 $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Commodity Contract [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

Level 3 [Member]

Electric portfolio [Member]

Natural gas portfolio [Member]

Discounted cash flow [Member]

Fair Value, Measurements, Recurring [Member]

Level 3 [Member]

Low [Member]

High [Member]

Weighted Average [Member]

Low [Member]

High [Member]

Weighted Average [Member]

Subsidiaries [Member]

Parent Company [Member]

Fair Value, Measurements, Recurring [Member]

Subsidiaries [Member]

Commodity Contract [Member]

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

Unrealized Gain (Loss) on Derivatives and Commodity Contracts

$4,700,000

($15,600,000)

$100,000

($14,200,000)

Derivative Assets

52,083,000

26,600,000

13,845,000

6,491,000

11,020,000

[1]

3,818,000

[1]

2,825,000

[1]

2,673,000

[1]

Derivative Liability

33,102,000

72,988,000

18,811,000

22,273,000

15,713,000

[1]

19,239,000

[1]

3,098,000

[1]

3,034,000

[1]

Price (per MWh)

19.08

17.06

44.36

47.09

35.77

38.74

Price (per MMBtu)

3.84

3.62

4.09

4.19

4.02

3.78

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

$8,700,000

$7,000,000

[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 $)	6 Months Ended	12 Months Ended	6 Months Ended	12 Months Ended	6 Months Ended	12 Months Ended	3 Months Ended		6 Months Ended		3 Months Ended		6 Months Ended		3 Months Ended		6 Months Ended		3 Months Ended		6 Months Ended		3 Months Ended		6 Months Ended		3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
	Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	Other Benefit [Member]	Other Benefit [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [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]
							Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	Other Benefit [Member]	Other Benefit [Member]	Other Benefit [Member]	Other Benefit [Member]	Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	Other Benefit [Member]	Other Benefit [Member]	Other Benefit [Member]	Other Benefit [Member]
Components of net periodic benefit cost:	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'
Service cost	($8,718)	($19,285)	($521)	($1,498)	($56)	($134)	$4,206	$4,934	$8,718	$9,643	$261	$375	$521	$749	$26	$32	$56	$67	$4,206	$4,934	$8,718	$9,643	$261	$375	$521	$749	$26	$32	$56	$67
Interest cost	-14,020	-24,754	-1,155	-2,045	-342	-664	6,965	6,182	14,020	12,377	577	511	1,155	1,022	159	155	342	332	6,965	6,182	14,020	12,377	577	511	1,155	1,022	159	155	342	332
Expected return on plan assets	'	'	'	'	'	'	-10,511	-9,696	-21,232	-19,548	0	0	0	0	-134	-109	-267	-218	-10,708	-10,094	-21,626	-20,343	0	0	0	0	-134	-109	-267	-218
Amortization of prior service cost	'	'	'	'	'	'	-495	-495	-990	-990	11	-4	22	-9	0	0	-197	0	-393	-393	-786	-787	11	-4	22	-8	1	8	2	14
Amortization of net loss (gain)	'	'	'	'	'	'	0	794	0	1,444	228	365	456	731	-130	18	0	34	3,359	5,221	6,597	10,306	365	548	730	1,096	-208	-108	-352	-142
Defined Benefit Plan, Net Periodic Benefit Cost	'	'	'	'	'	'	$165	$1,719	$516	$2,926	$1,077	$1,247	$2,154	$2,493	($79)	$96	($66)	$215	$3,429	$5,850	$6,923	$11,196	$1,214	$1,430	$2,428	$2,859	($156)	($22)	($219)	$53

Retirement_Benefits_Change_in_

Retirement Benefits Change in Net Benefit Obligation (Details) (USD $)	6 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 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	-8,718	-19,285
Interest cost	14,020	24,754
Amendments	0	0
Actuarial loss/(gain)	1,878	-48,559
Benefits paid	-25,408	-38,453
Medicare part D subsidiary received	0	0
Benefit obligation at end of period	572,525	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	-521	-1,498
Interest cost	1,155	2,045
Amendments	0	478
Actuarial loss/(gain)	0	-1,687
Benefits paid	-942	-6,850
Medicare part D subsidiary received	0	'
Benefit obligation at end of period	48,013	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	-56	-134
Interest cost	342	664
Amendments	0	0
Actuarial loss/(gain)	-932	-2,240
Benefits paid	-739	-1,536
Medicare part D subsidiary received	117	245
Benefit obligation at end of period	$13,783	$14,939

Retirement_Benefits_Activity_D

Retirement Benefits Activity (Details) (USD $)	3 Months Ended	6 Months Ended	3 Months Ended	6 Months Ended	3 Months Ended	6 Months Ended	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014
	Qualified Pension Benefits [Member]	Qualified Pension Benefits [Member]	SERP Pension Benefits [Member]	SERP Pension Benefits [Member]	Other Benefit [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	$0.30	'
Company Contribution	$3	$6	$0.50	$0.90	$0.10	$0.30	'	'	'	'	'

Regulation_and_Rates_Details

Regulation and Rates (Details) (USD $)

6 Months Ended

11 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Jun. 30, 2014

Dec. 31, 2013

Jul. 02, 2013

Jan. 02, 2014

1-May-14

Jul. 02, 2013

1-May-14

Jul. 02, 2013

Nov. 01, 2013

Dec. 31, 2014

1-May-14

Dec. 01, 2014

Subsidiaries [Member]

Decoupling Mechanism [Member]

Expedited Rate Filing [Member]

Power Cost Only Rate Case (PCORC) [Member]

Purchased Gas Adjustment (PGA) [Member]

Scenario, Forecast [Member]

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

Conservation Rider [Member]

Subsequent Event [Member]

Electric [Member]

Natural Gas [Member]

Subsidiaries [Member]

Power Cost Only Rate Case (PCORC) [Member]

Electric [Member]

Natural Gas [Member]

Electric [Member]

Natural Gas [Member]

Electric [Member]

Natural Gas [Member]

Electric [Member]

Natural Gas [Member]

Electric [Member]

Natural Gas [Member]

Subsidiaries [Member]

Electric [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)

$10.60

$21.40

$10.80

$30.70

($2)

($10.50)

$11

$5.60

$12.20

$0.30

$9.60

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

3.00%

2.20%

0.50%

1.00%

0.10%

1.10%

1.50%

-0.20%

-0.50%

0.40%

0.60%

0.50%

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 $)	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 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	'	'	'	$1,290,000	$1,380,000	'	'	'

Accumulated_Other_Comprehensiv2

Accumulated Other Comprehensive Income - Changes by Component (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014
In Thousands, unless otherwise specified			Subsidiaries [Member]	Subsidiaries [Member]	Accumulated Defined Benefit Plans Adjustment [Member]	Accumulated Defined Benefit Plans Adjustment [Member]	Accumulated Defined Benefit Plans Adjustment [Member]	Accumulated Defined Benefit Plans Adjustment [Member]	Derivative [Member]	Derivative [Member]	Derivative [Member]	Derivative [Member]	Interest Rate Swap [Member]	Interest Rate Swap [Member]	Interest Rate Swap [Member]	Interest Rate Swap [Member]	Comprehensive Income [Member]	Comprehensive Income [Member]	Comprehensive Income [Member]	Comprehensive Income [Member]
							Subsidiaries [Member]	Subsidiaries [Member]			Subsidiaries [Member]	Subsidiaries [Member]			Subsidiaries [Member]	Subsidiaries [Member]			Subsidiaries [Member]	Subsidiaries [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'
Beginning balance	$47,164	$47,715	($91,438)	($95,739)	$48,305	$48,514	($85,404)	($87,405)	($358)	($705)	($1,309)	($2,027)	$0	($94)	($6,228)	($6,307)	$47,947	$47,715	($92,941)	($95,739)
Other comprehensive income (loss) before reclassifications	'	'	'	'	-615	-615	-615	-615	0	0	0	0	0	0	0	0	-615	-615	-615	-615
Amounts reclassified from accumulated other comprehensive income (loss), net of tax	'	'	'	'	-168	-377	2,039	4,040	0	347	0	718	0	94	79	158	-168	64	2,118	4,916
Net current-period other comprehensive income (loss)	'	'	'	'	-783	-992	1,424	3,425	0	347	0	718	0	94	79	158	-783	-551	1,503	4,301
Ending balance	$47,164	$47,715	($91,438)	($95,739)	$47,522	$47,522	($83,980)	($83,980)	($358)	($358)	($1,309)	($1,309)	$0	$0	($6,149)	($6,149)	$47,164	$47,164	($91,438)	($91,438)

Accumulated_Other_Comprehensiv3

Accumulated Other Comprehensive Income - Reclassification Location (Details) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

In Thousands, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Subsidiaries [Member]

Accumulated Defined Benefit Plans Adjustment [Member]

Reclassification out of Accumulated Other Comprehensive Income [Member]

Interest Rate Contract [Member]

Electric Derivative [Member]

Qualified Pension Benefits [Member]

Amortization of Net Gain (Loss) [Member]

Amortization of Prior Service Cost [Member]

Derivative [Member]

Interest Rate Swap [Member]

Comprehensive Income [Member]

Subsidiaries [Member]

Interest Expense [Member]

Purchased Electricity [Member]

Pension Cost [Member]

Subsidiaries [Member]

Reclassification out of Accumulated Other Comprehensive Income [Line Items]

Accumulated Other Comprehensive Income (Loss), Net of Tax

$47,164

$47,715

($91,438)

($95,739)

$47,522

$48,305

$48,514

($83,980)

($85,404)

($87,405)

($358)

($705)

($1,309)

($2,027)

($94)

($6,149)

($6,228)

($6,307)

$47,164

$47,947

$47,715

($91,438)

($92,941)

($95,739)

Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent

-1,325

-144

-2,639

-122

-244

-534

164

-1,104

-2,786

386

-678

709

-1,210

-3,135

-5,272

-6,213

-10,479

-98

[1]

-1,177

[1]

-456

-2,209

-3,516

[2]

-5,661

[2]

-6,975

[2]

-11,260

[2]

484

[1]

499

[1]

1,165

999

381

[2]

389

[2]

762

[2]

781

[2]

Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent

464

924

187

-57

386

975

-135

237

-248

422

1,097

1,845

2,175

3,666

Comprehensive income (loss)

40,330

659

148,154

169,228

59,337

28,621

183,217

213,835

251

-1,302

-2,396

-2,117

-3,506

-4,914

-8,782

-861

-94

-1,715

-79

-158

-347

107

-718

-1,811

251

-441

461

-788

-2,038

-3,427

-4,038

-6,813

Other Comprehensive Income (Loss), before Reclassifications, Net of Tax

-615

Other comprehensive income (loss) before reclassifications

-168

-377

2,039

4,040

347

718

158

-168

2,118

4,916

Amortization Of Financing Cash Flow Hedge Contracts To Earnings During Period Net Of Tax

158

Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax

-347

107

-718

-1,811

Other Comprehensive Income Reclassification Of Net Unrealized Gain Loss On Interest Rate Swaps During Period Net Of Tax

-861

-94

-1,715

Amounts reclassified from accumulated other comprehensive income (loss), net of tax

($783)

($992)

$1,424

$3,425

$347

$718

$94

$79

$158

($783)

($551)

$1,503

$4,301

[1]

(a)B These accumulated OCI components are included in the computation of net periodic pension cost (see Note 5 for additional details).

[2]

(a) These accumulated OCI components are included in the computation of net periodic pension cost (see Note 5 for additional details).

Other_Jefferson_County_Public_

Other Jefferson County Public Utility District (Details) (Jefferson County Public Utility District [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Mar. 30, 2013	Mar. 28, 2014	Oct. 31, 2013	Mar. 28, 2014	Oct. 31, 2013
	Jun. 30, 2014	Mar. 30, 2013	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	'	'	'	'	'

Other_Term_Loan_Details

Other (Term Loan) (Details) (USD $)	1 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Debt Instrument [Line Items]	'
Long-term Debt, Maturities, Repayment Terms	'3
Loans [Member]	'
Debt Instrument [Line Items]	'
Long-term Debt, Gross	299
Long-term Debt [Member]	'
Debt Instrument [Line Items]	'
Long-term Debt, Maturities, Repayment Terms	'2

Other_Treasury_Grant_Details

Other (Treasury Grant) (Details) (USD $)	6 Months Ended		11 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Debt Instrument [Line Items]	'	'	'
Treasury grant payment received	$107,794	$0	'
American Recovery and Reinvestment Tax Act of 2009, Grant Amortization Period	'10 years	'	'
Subsidiaries [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Treasury grant payment received	$107,794	$0	'
American Recovery and Reinvestment Tax Act of 2009, Grant Amortization Period	'	'	'10 years