Puget Sound Energy 10-Q 3 Aug 22 2022 Q2 Quarterly report Financial data

Cover

Cover	6 Months Ended
	Jun. 30, 2022 shares
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2022
Document Transition Report	false
Entity File Number	1-16305
Entity Tax Identification Number	91-1969407
Entity Incorporation, State or Country Code	WA
Entity Address, Address Line One	355 110th Ave NE
Entity Address, City or Town	Bellevue
Entity Address, State or Province	WA
Entity Address, Postal Zip Code	98004
City Area Code	(425)
Local Phone Number	454-6363
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Shell Company	false
Document Fiscal Period Focus	Q2
Entity Central Index Key	0001085392
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding	200
Document Fiscal Year Focus	2022
Amendment Flag	false
Entity Emerging Growth Company	false
Entity Registrant Name	PUGET ENERGY INC /WA
Subsidiaries [Member]
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2022
Document Transition Report	false
Entity File Number	1-4393
Entity Tax Identification Number	91-0374630
Entity Incorporation, State or Country Code	WA
Entity Address, Address Line One	355 110th Ave NE
Entity Address, City or Town	Bellevue
Entity Address, State or Province	WA
Entity Address, Postal Zip Code	98004
City Area Code	(425)
Local Phone Number	454-6363
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Shell Company	false
Document Fiscal Period Focus	Q2
Entity Central Index Key	0000081100
Current Fiscal Year End Date	--06-30
Entity Common Stock, Shares Outstanding	85,903,791
Document Fiscal Year Focus	2022
Amendment Flag	false
Entity Emerging Growth Company	false
Entity Registrant Name	PUGET SOUND ENERGY, INC.

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Operating revenue:
Electric	$ 594,331	$ 563,822	$ 1,350,708	$ 1,322,414
Natural gas	236,054	195,124	662,402	588,030
Other	11,991	10,444	22,703	19,032
Total operating revenue	842,376	769,390	2,035,813	1,929,476
Energy costs:
Purchased electricity	212,391	162,515	450,594	367,925
Electric generation fuel	46,498	56,448	107,142	116,866
Residential exchange	(16,783)	(17,592)	(39,853)	(43,394)
Purchased natural gas	92,452	62,829	269,785	217,844
Unrealized (gain) loss on derivative instruments, net	9,273	(61,276)	(122,648)	(84,278)
Utility operations and maintenance	160,933	150,167	331,233	310,707
Non-utility expense and other	15,299	9,566	30,718	19,472
Depreciation & amortization	165,676	165,930	330,252	374,361
Conservation amortization	25,906	21,901	56,047	55,961
Taxes other than income taxes	86,544	76,837	207,921	187,147
Total operating expenses	798,189	627,325	1,621,191	1,522,611
Operating income (loss)	44,187	142,065	414,622	406,865
Other income (expense):
Other income	13,231	14,490	26,395	28,120
Other expense	(4,538)	(2,350)	(7,692)	(3,860)
Interest charges:
AFUDC	3,974	3,775	8,103	7,361
Interest expense	(86,194)	(90,407)	(172,662)	(179,767)
Income (loss) before income taxes	(29,340)	67,573	268,766	258,719
Income tax (benefit) expense	4,156	12,331	23,967	14,484
Net income (loss)	(33,496)	55,242	244,799	244,235
Subsidiaries [Member]
Operating revenue:
Electric	594,331	563,822	1,350,708	1,322,414
Natural gas	236,054	195,124	662,402	588,030
Other	11,991	10,444	22,668	19,032
Total operating revenue	842,376	769,390	2,035,778	1,929,476
Energy costs:
Purchased electricity	212,391	162,515	450,594	367,925
Electric generation fuel	46,498	56,448	107,142	116,866
Residential exchange	(16,783)	(17,592)	(39,853)	(43,394)
Purchased natural gas	92,452	62,829	269,785	217,844
Unrealized (gain) loss on derivative instruments, net	9,273	(61,276)	(122,648)	(84,278)
Utility operations and maintenance	160,933	150,167	331,233	310,707
Non-utility expense and other	11,842	8,952	24,656	18,370
Depreciation & amortization	164,009	165,803	327,713	374,165
Conservation amortization	25,906	21,901	56,047	55,961
Taxes other than income taxes	86,243	76,837	207,359	187,147
Total operating expenses	792,764	626,584	1,612,028	1,521,313
Operating income (loss)	49,612	142,806	423,750	408,163
Other income (expense):
Other income	11,005	11,427	21,973	22,461
Other expense	(4,538)	(2,350)	(7,692)	(3,860)
Interest charges:
AFUDC	3,974	3,775	8,103	7,361
Interest expense	(62,663)	(62,869)	(125,807)	(125,240)
Income (loss) before income taxes	(2,610)	92,789	320,327	308,885
Income tax (benefit) expense	3,708	14,425	38,564	31,051
Net income (loss)	$ (6,318)	$ 78,364	$ 281,763	$ 277,834

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net Income (Loss) Attributable to Parent	$ (33,496)	$ 55,242	$ 244,799	$ 244,235
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Net unrealized gain (loss) from pension and postretirement plans, net of tax	1,831	2,386	3,662	4,771
Other comprehensive income (loss)	1,831	2,386	3,662	4,771
Comprehensive Income (Loss), Net of Tax, Attributable to Parent, Total	(31,665)	57,628	248,461	249,006
Subsidiaries [Member]
Net Income (Loss) Attributable to Parent	(6,318)	78,364	281,763	277,834
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Net unrealized gain (loss) from pension and postretirement plans, net of tax	3,587	4,459	7,175	8,917
Amortization Of Financing Cash Flow Hedge Contracts To Earnings During Period Net Of Tax	98	96	195	192
Other comprehensive income (loss)	3,685	4,555	7,370	9,109
Comprehensive Income (Loss), Net of Tax, Attributable to Parent, Total	$ (2,633)	$ 82,919	$ 289,133	$ 286,943

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net unrealized gain (loss) from pension and postretirement plans, net of tax	$ 488	$ 634	$ 975	$ 1,268
Subsidiaries [Member]
Net unrealized gain (loss) from pension and postretirement plans, net of tax	953	1,184	1,906	2,369
Amortization of treasury interest rate swaps to earnings, net of tax	$ 24	$ 26	$ 50	$ 52

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Utility Plant [Abstract]
Public Utilities Property Plant And Equipment Electric Plant	$ 10,003,646	$ 9,729,643
Public Utilities Property Plant And Equipment Gas Plant	4,612,299	4,498,198
Public Utilities Property Plant And Equipment Common Plant	1,112,583	1,155,567
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(4,185,970)	(4,031,458)
Public Utilities, Property, Plant and Equipment, Net, Total	11,542,558	11,351,950
Other Property And Investments [Abstract]
Goodwill	1,656,513	1,656,513
Other Property And Investments	327,173	324,897
Total Other Property And Investments	1,983,686	1,981,410
Assets, Current [Abstract]
Cash and Cash Equivalents, at Carrying Value	56,861	56,946
Restricted Cash and Cash Equivalents, Current	22,184	46,204
Accounts Receivable, after Allowance for Credit Loss, Current	351,727	398,895
Unbilled Revenues	160,166	271,606
Other Inventory, Supplies, Gross	123,075	113,287
Fuel And Gas Inventory At Average Cost	90,895	59,393
Derivative Asset, Current	220,724	128,210
Prepaid Expense and Other Assets, Current	51,883	46,293
Power Contract Acquisition Adjustment Gain Current	17,560	17,274
Assets, Current, Total	1,095,075	1,138,108
Other Longterm And Regulatory Assets [Abstract]
Power Cost Adjustment Mechanism Asset, Noncurrent	63,134	79,546
purchase gas adjustment, long-term	54,534	57,935
Regulatory Assets Related To Power Contracts	8,588	9,689
Other Regulatory Assets	797,867	815,058
Derivative Asset, Noncurrent	58,317	26,197
Power Contract Acquisition Adjustment Non Current	56,588	63,660
Operating Lease, Right-of-Use Asset	179,909	184,957
Other Assets, Noncurrent	167,019	163,374
Total Longterm And Regulatory Assets	1,385,956	1,400,416
Assets, Total	16,007,275	15,871,884
Capitalization [Abstract]
Common stock	0	0
Additional Paid in Capital	3,523,532	3,523,532
Retained Earnings (Accumulated Deficit)	1,310,782	1,067,216
Accumulated Other Comprehensive Income (Loss), Net of Tax	(23,770)	(27,432)
Stockholders' Equity Attributable to Parent, Total	4,810,544	4,563,316
Long-term Debt, Excluding Current Maturities [Abstract]
Senior Notes, Noncurrent	4,662,000	4,662,000
Long-term Pollution Control Bond	161,860	161,860
Other Long-term Debt, Noncurrent	2,034,300	1,583,300
Debt discount and other	(200,959)	(203,394)
Long-term Debt, Excluding Current Maturities, Total	6,657,201	6,203,766
Capitalization, Long-term Debt and Equity, Total	11,467,745	10,767,082
Liabilities, Current [Abstract]
Accounts Payable, Current	386,072	444,384
Short-term Debt	64,000	140,000
Long-term Debt, Current Maturities	0	450,000
Accrued Expenses [Abstract]
Taxes Payable, Current	110,435	127,398
Employee-related Liabilities, Current	49,236	47,936
Interest Payable, Current	61,698	67,807
Derivative Liability, Current	53,177	63,309
Power Contract Acquisition Adjustment Loss Current	1,682	1,785
Operating Lease, Liability, Current	21,135	20,398
Other Liabilities, Current	73,630	62,406
Liabilities, Current, Total	821,065	1,425,423
Longterm And Regulatory Liabilities [Abstract]
Deferred Tax and Other Liabilities, Noncurrent	937,939	912,484
Derivative Liability, Noncurrent	10,414	40,965
Regulatory Liabilities, Noncurrent	911,556	844,184
Deferred Tax Liabilities, Regulatory Assets and Liabilities	838,796	865,976
Regulatory Liabilities Related To Power Contracts	74,148	80,934
Power Contract Acquisition Adjustment Loss Non Current	6,906	7,904
Operating Lease, Liability, Noncurrent	166,238	172,510
Finance Lease, Liability, Noncurrent	103,778	105,303
Other Deferred Credits	668,690	649,119
Total Longterm And Regulatory Liabilities	3,718,465	3,679,379
Commitments and Contingencies
Liabilities and Equity, Total	16,007,275	15,871,884
Subsidiaries [Member]
Utility Plant [Abstract]
Public Utilities Property Plant And Equipment Electric Plant	11,789,175	11,535,976
Public Utilities Property Plant And Equipment Gas Plant	5,167,725	5,054,622
Public Utilities Property Plant And Equipment Common Plant	1,134,290	1,177,598
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(6,548,632)	(6,416,246)
Public Utilities, Property, Plant and Equipment, Net, Total	11,542,558	11,351,950
Other Property And Investments [Abstract]
Other Property And Investments	78,707	74,602
Total Other Property And Investments	78,707	74,602
Assets, Current [Abstract]
Cash and Cash Equivalents, at Carrying Value	52,302	50,043
Restricted Cash and Cash Equivalents, Current	22,184	46,204
Accounts Receivable, after Allowance for Credit Loss, Current	353,059	402,602
Unbilled Revenues	160,166	271,606
Other Inventory, Supplies, Gross	123,075	113,287
Fuel And Gas Inventory At Average Cost	89,271	58,129
Derivative Asset, Current	220,724	128,210
Prepaid Expense and Other Assets, Current	51,883	46,293
Assets, Current, Total	1,072,664	1,116,374
Other Longterm And Regulatory Assets [Abstract]
Power Cost Adjustment Mechanism Asset, Noncurrent	63,134	79,546
purchase gas adjustment, long-term	54,534	57,935
Other Regulatory Assets	797,867	815,058
Derivative Asset, Noncurrent	58,317	26,197
Operating Lease, Right-of-Use Asset	179,909	184,957
Other Assets, Noncurrent	163,554	162,391
Total Longterm And Regulatory Assets	1,317,315	1,326,084
Assets, Total	14,011,244	13,869,010
Capitalization [Abstract]
Common stock	859	859
Additional Paid in Capital	3,485,105	3,485,105
Retained Earnings (Accumulated Deficit)	1,248,437	982,607
Accumulated Other Comprehensive Income (Loss), Net of Tax	(105,771)	(113,141)
Stockholders' Equity Attributable to Parent, Total	4,628,630	4,355,430
Long-term Debt, Excluding Current Maturities [Abstract]
Senior Notes, Noncurrent	4,662,000	4,662,000
Long-term Pollution Control Bond	161,860	161,860
Debt discount and other	(38,108)	(39,141)
Long-term Debt, Excluding Current Maturities, Total	4,785,752	4,784,719
Capitalization, Long-term Debt and Equity, Total	9,414,382	9,140,149
Liabilities, Current [Abstract]
Accounts Payable, Current	385,938	451,716
Short-term Debt	55,000	140,000
Accrued Expenses [Abstract]
Taxes Payable, Current	110,739	133,406
Employee-related Liabilities, Current	49,236	47,936
Interest Payable, Current	51,957	51,832
Derivative Liability, Current	53,177	63,309
Operating Lease, Liability, Current	21,135	20,398
Other Liabilities, Current	73,630	62,406
Liabilities, Current, Total	800,812	971,003
Longterm And Regulatory Liabilities [Abstract]
Deferred Tax and Other Liabilities, Noncurrent	1,101,062	1,084,203
Derivative Liability, Noncurrent	10,414	40,965
Regulatory Liabilities, Noncurrent	910,292	842,920
Deferred Tax Liabilities, Regulatory Assets and Liabilities	839,355	866,541
Operating Lease, Liability, Noncurrent	166,238	172,510
Finance Lease, Liability, Noncurrent	103,778	105,303
Other Deferred Credits	664,911	645,416
Total Longterm And Regulatory Liabilities	3,796,050	3,757,858
Commitments and Contingencies
Liabilities and Equity, Total	$ 14,011,244	$ 13,869,010

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
ASSETS
Construction work in progress	$ 778,667	$ 870,204
Assets, Current [Abstract]
Allowance for doubtful accounts	42,342	34,958
Common shareholder’s equity:
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	778,667	870,204
Allowance for doubtful accounts	$ 42,342	$ 34,958
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	200	200
Subsidiaries [Member]
ASSETS
Construction work in progress	$ 778,667	$ 870,204
Assets, Current [Abstract]
Allowance for doubtful accounts	42,342	34,958
Common shareholder’s equity:
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	778,667	870,204
Allowance for doubtful accounts	$ 42,342	$ 34,958
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	85,903,791	85,903,791

CONSOLIDATED STATEMENTS OF COMM

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER’S EQUITY Statement - USD ($) $ in Thousands	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	AOCI Attributable to Parent [Member]	Subsidiaries [Member]	Subsidiaries [Member] Common Stock [Member]	Subsidiaries [Member] Additional Paid-in Capital [Member]	Subsidiaries [Member] Retained Earnings [Member]	Subsidiaries [Member] AOCI Attributable to Parent [Member]
Beginning Balance (in shares) at Dec. 31, 2020		200					85,903,791
Beginning Balance at Dec. 31, 2020	$ 4,139,882	$ 0	$ 3,313,532	$ 912,787	$ (86,437)	$ 4,181,409	$ 859	$ 3,485,105	$ 876,401	$ (180,956)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss) Attributable to Parent	188,993			188,993		199,470			199,470
Dividends, Common Stock	(22,939)			(22,939)		(52,053)			(52,053)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	2,385				2,385	4,554				4,554
Ending Balance (in shares) at Mar. 31, 2021		200					85,903,791
Ending Balance at Mar. 31, 2021	4,308,321	$ 0	3,313,532	1,078,841	(84,052)	4,333,380	$ 859	3,485,105	1,023,818	(176,402)
Beginning Balance (in shares) at Dec. 31, 2020		200					85,903,791
Beginning Balance at Dec. 31, 2020	4,139,882	$ 0	3,313,532	912,787	(86,437)	4,181,409	$ 859	3,485,105	876,401	(180,956)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss) Attributable to Parent	244,235					277,834
Ending Balance (in shares) at Jun. 30, 2021		200					85,903,791
Ending Balance at Jun. 30, 2021	4,552,735	$ 0	3,523,532	1,110,869	(81,666)	4,371,677	$ 859	3,485,105	1,057,560	(171,847)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Proceeds from Contributions from Parent	210,000
Beginning Balance (in shares) at Mar. 31, 2021		200					85,903,791
Beginning Balance at Mar. 31, 2021	4,308,321	$ 0	3,313,532	1,078,841	(84,052)	4,333,380	$ 859	3,485,105	1,023,818	(176,402)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss) Attributable to Parent	55,242			55,242		78,364			78,364
Dividends, Common Stock	(23,214)			(23,214)		(44,622)			(44,622)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	2,386				2,386	4,555				4,555
Ending Balance (in shares) at Jun. 30, 2021		200					85,903,791
Ending Balance at Jun. 30, 2021	4,552,735	$ 0	3,523,532	1,110,869	(81,666)	$ 4,371,677	$ 859	3,485,105	1,057,560	(171,847)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Proceeds from Contributions from Parent	$ 210,000		210,000
Beginning Balance (in shares) at Dec. 31, 2021	200	200				85,903,791	85,903,791
Beginning Balance at Dec. 31, 2021	$ 4,563,316	$ 0	3,523,532	1,067,216	(27,432)	$ 4,355,430	$ 859	3,485,105	982,607	(113,141)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss) Attributable to Parent	278,295			278,295		288,081			288,081
Dividends, Common Stock	(939)			(939)		(13,896)			(13,896)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	1,831				1,831	3,685				3,685
Ending Balance (in shares) at Mar. 31, 2022		200					85,903,791
Ending Balance at Mar. 31, 2022	$ 4,842,503	$ 0	3,523,532	1,344,572	(25,601)	$ 4,633,300	$ 859	3,485,105	1,256,792	(109,456)
Beginning Balance (in shares) at Dec. 31, 2021	200	200				85,903,791	85,903,791
Beginning Balance at Dec. 31, 2021	$ 4,563,316	$ 0	3,523,532	1,067,216	(27,432)	$ 4,355,430	$ 859	3,485,105	982,607	(113,141)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss) Attributable to Parent	$ 244,799					$ 281,763
Ending Balance (in shares) at Jun. 30, 2022	200	200				85,903,791	85,903,791
Ending Balance at Jun. 30, 2022	$ 4,810,544	$ 0	3,523,532	1,310,782	(23,770)	$ 4,628,630	$ 859	3,485,105	1,248,437	(105,771)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Proceeds from Contributions from Parent	0
Beginning Balance (in shares) at Mar. 31, 2022		200					85,903,791
Beginning Balance at Mar. 31, 2022	4,842,503	$ 0	3,523,532	1,344,572	(25,601)	4,633,300	$ 859	3,485,105	1,256,792	(109,456)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss) Attributable to Parent	(33,496)			(33,496)		(6,318)			(6,318)
Dividends, Common Stock	(294)			(294)		(2,037)			(2,037)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	$ 1,831				1,831	$ 3,685				3,685
Ending Balance (in shares) at Jun. 30, 2022	200	200				85,903,791	85,903,791
Ending Balance at Jun. 30, 2022	$ 4,810,544	$ 0	$ 3,523,532	$ 1,310,782	$ (23,770)	$ 4,628,630	$ 859	$ 3,485,105	$ 1,248,437	$ (105,771)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended				6 Months Ended		12 Months Ended
	Jun. 30, 2022	Mar. 31, 2022	Jun. 30, 2021	Mar. 31, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net Income (Loss) Attributable to Parent	$ (33,496)	$ 278,295	$ 55,242	$ 188,993	$ 244,799	$ 244,235
Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]
Depreciation & amortization	165,676		165,930		330,252	374,361
Conservation amortization	25,906		21,901		56,047	55,961
Deferred Income Taxes and Tax Credits					(2,699)	23,377
Unrealized Gain (Loss) on Derivatives					(122,648)	(84,278)
Afudc Equity					(13,887)	(12,139)
Monetized production tax credits					0	(45,562)
Other Noncash Income (Expense)					4,180	(12,759)
Increase (Decrease) in Other Regulatory Assets					9,939	(50,120)
Purchased gas adjustment					3,401	38,230
Increase (Decrease) in Other Operating Assets					(11,079)	(13,087)
Increase (Decrease) in Operating Capital [Abstract]
Increase (Decrease) in Accounts and Other Receivables					158,608	118,203
Increase (Decrease) in Materials and Supplies					(9,788)	(2,519)
Increase (Decrease) in Fuel Inventories					(31,502)	(14,825)
Increase (Decrease) in Prepaid Expense and Other Assets					(5,757)	(783)
Increase (Decrease) in Accounts Payable					(50,649)	(24,775)
Increase (Decrease) in Income Taxes Payable					(16,963)	(9,599)
Increase (Decrease) in Other Accounts Payable and Accrued Liabilities					(9,514)	(15,114)
Net Cash Provided by (Used in) Operating Activities, Total					532,740	568,807
Net Cash Provided by (Used in) Investing Activities [Abstract]
Construction expenditures excluding equity allowance for funds used during construction					(483,754)	(442,981)
Payments for (Proceeds from) Other Investing Activities					(566)	60
Net Cash Provided by (Used in) Investing Activities, Total					(484,320)	(442,921)
Net Cash Provided by (Used in) Financing Activities [Abstract]
Proceeds from (Repayments of) Short-term Debt					(76,000)	(142,500)
Payments of Dividends					(1,233)	(46,153)
Proceeds from Contributions from Parent			210,000		0	210,000
Proceeds from Issuance of Long-term Debt					448,075	514,875
Repayments of Long-term Debt					(450,000)	(66)
Repayments of Debt					0	(210,000)
Proceeds from (Payments for) Other Financing Activities					6,633	10,982
Net Cash Provided by (Used in) Financing Activities, Total					(72,525)	337,138
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total					(24,105)	463,024
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Beginning Balance		103,150		81,851	103,150	81,851	$ 81,851
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Ending Balance	79,045		544,875		79,045	544,875	103,150
Supplemental Cash Flow Information [Abstract]
Interest Paid, Excluding Capitalized Interest, Operating Activities					163,329	160,986
Proceeds from Income Tax Refunds					25,244	13,151
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Capital Expenditures Incurred but Not yet Paid					67,845	54,078
Subsidiaries [Member]
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net Income (Loss) Attributable to Parent	(6,318)	288,081	78,364	199,470	281,763	277,834
Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]
Depreciation & amortization	164,009		165,803		327,713	374,165
Conservation amortization	25,906		21,901		56,047	55,961
Deferred Income Taxes and Tax Credits					(12,285)	27,413
Unrealized Gain (Loss) on Derivatives					(122,648)	(84,278)
Afudc Equity					(13,887)	(12,139)
Monetized production tax credits					0	(45,562)
Other Noncash Income (Expense)					(1,299)	(18,068)
Increase (Decrease) in Other Regulatory Assets					9,939	(50,120)
Purchased gas adjustment					3,401	38,230
Increase (Decrease) in Other Operating Assets					(6,523)	(7,850)
Increase (Decrease) in Operating Capital [Abstract]
Increase (Decrease) in Accounts and Other Receivables					160,983	120,026
Increase (Decrease) in Materials and Supplies					(9,788)	(2,519)
Increase (Decrease) in Fuel Inventories					(31,142)	(14,825)
Increase (Decrease) in Prepaid Expense and Other Assets					(5,757)	(783)
Increase (Decrease) in Accounts Payable					(58,115)	(10,865)
Increase (Decrease) in Income Taxes Payable					(22,667)	(5,732)
Increase (Decrease) in Other Accounts Payable and Accrued Liabilities					(3,279)	(15,122)
Net Cash Provided by (Used in) Operating Activities, Total					552,456	625,766
Net Cash Provided by (Used in) Investing Activities [Abstract]
Construction expenditures excluding equity allowance for funds used during construction					(483,117)	(439,374)
Payments for (Proceeds from) Other Investing Activities					(566)	60
Net Cash Provided by (Used in) Investing Activities, Total					(483,683)	(439,314)
Net Cash Provided by (Used in) Financing Activities [Abstract]
Proceeds from (Repayments of) Short-term Debt					(85,000)	(142,500)
Payments of Dividends					(15,933)	(96,675)
Repayments of Long-term Debt					0	(66)
Proceeds from (Payments for) Other Financing Activities					10,399	11,359
Net Cash Provided by (Used in) Financing Activities, Total					(90,534)	(227,882)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total					(21,761)	(41,430)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Beginning Balance		$ 96,247		$ 80,721	96,247	80,721	80,721
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Ending Balance	$ 74,486		$ 39,291		74,486	39,291	$ 96,247
Supplemental Cash Flow Information [Abstract]
Interest Paid, Excluding Capitalized Interest, Operating Activities					115,192	114,854
Proceeds from Income Tax Refunds					55,131	21,816
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Capital Expenditures Incurred but Not yet Paid					$ 67,845	$ 54,078

Summary of Consolidation and Si

Summary of Consolidation and Significant Accounting Policy	6 Months Ended
	Jun. 30, 2022
Accounting Policies [Abstract]
Significant Accounting Policies	Summary of Consolidation and Significant Accounting Policy 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. Puget Energy also has a wholly-owned non-regulated subsidiary, Puget LNG, LLC (Puget LNG), which has the sole purpose of owning, developing and financing the non-regulated activity of the Tacoma liquefied natural gas (LNG) facility. PSE and Puget LNG are considered related parties with similar ownership by Puget Energy. Therefore, capital and operating costs that are incurred by PSE and allocated to Puget LNG are related party transactions by nature. In 2009, Puget Holdings, LLC (Puget Holdings), owned by a consortium of long-term infrastructure investors, completed its merger with Puget Energy (the merger). As a result of the merger, all of Puget Energy’s common stock is indirectly owned by Puget Holdings. The acquisition of Puget Energy was accounted for in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 805, “Business Combinations”, as of the date of the merger. ASC 805 requires the acquirer to recognize and measure identifiable assets acquired and liabilities assumed at fair value as of the merger date. The consolidated financial statements of Puget Energy reflect the accounts of Puget Energy and its subsidiaries. PSE’s consolidated financial statements include the accounts of PSE and its subsidiary. Puget Energy and PSE are collectively referred to herein as “the Company”. The consolidated financial statements are presented after elimination of all significant intercompany items and transactions. PSE’s consolidated financial statements continue to be accounted for on a historical basis and do not include any ASC 805, “Business Combinations” purchase accounting adjustments. The preparation of financial statements in conformity with U.S. Generally Accepted Accounting Principles (GAAP) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates. Allowance for Credit Losses Management measures expected credit losses on trade receivables on a collective basis by receivable type, which include electric retail receivables, natural gas retail receivables, and electric wholesale receivables. The estimate of expected credit losses considers historical credit loss information that is adjusted for current conditions and reasonable and supportable forecasts. The allowance increased during both periods due to both an increase in the provision combined with a reduction in receivables charged-off during the period. T he Ratepayer Assistance and Preservation of Essential Services proclamation issued by the Washington State governor in April 2020 included a moratorium on disconnecting customers, which resulted in a cessation of account receivable write-offs for non-payment. This moratorium ended on September 30, 2021, however, customer disconnects are only performed with approval from the Washington Utilities and Transportation Commission (Washington Commission) . The following table presents the activity in the allowance for credit losses for accounts receivable for the six months ended June 30, 2022 and 2021: Puget Energy and Six Months (Dollars in Thousands) 2022 2021 Allowance for credit losses: Beginning balance $ 34,958 $ 20,080 Provision for credit loss expense 1 15,727 18,421 Receivables charged-off (8,343) (5,060) Total ending allowance balance $ 42,342 $ 33,441 _______________ 1 $5.1 million and $5.2 million of provision were deferred as cost specific to COVID-19 for the six months ended June 30, 2022 and 2021, respectively. Tacoma LNG Facility On February 1, 2022, the Tacoma LNG facility at the Port of Tacoma completed commissioning and commenced commercial operations. In December 2019, the Puget Sound Clean Air Agency issued the air quality permit for the facility, and the Pollution Hearings Control Board of Washington State upheld the approval following extended litigation. The Tacoma LNG facility will provide peak-shaving services to PSE’s natural gas customers, and provide LNG as fuel to transportation customers, particularly in the marine market at a lower cost due to the facility's scale. Pursuant to an order by the Washington Commission, PSE will be allocated approximately 43.0% of common capital and operating costs, consistent with the regulated portion of the Tacoma LNG facility. The remaining 57.0% of common capital and operating costs of the Tacoma LNG facility will be allocated to Puget LNG. Per this allocation of costs, $246.5 million and $244.7 million of non-utility plant and construction work in progress related to Puget LNG's portion of the Tacoma LNG facility is reported in the Puget Energy "Other property and investments" line item as of June 30, 2022 and December 31, 2021, respectively. Additionally, $5.4 million and $0.5 million of operating costs are reported in the Puget Energy "Non-utility expense and other" financial statement line item for the six months ended June 30, 2022, and June 30, 2021, respectively. Further, $242.0 million and $239.6 million of natural gas plant and construction work in progress related to PSE’s portion of the Tacoma LNG facility is reported in the PSE “Utility plant - Natural gas plant” financial statement line item as of June 30, 2022 and December 31, 2021, respectively, as PSE is a regulated entity. Variable Interest Entities On April 12, 2017, PSE entered into a power purchase agreement (PPA) with Skookumchuck Wind Energy Project, LLC (Skookumchuck) pursuant to which Skookumchuck would develop a wind generation facility and, once completed, sell bundled energy and associated attributes, namely renewable energy certificates (RECs) to PSE over a term of 20 years. Skookumchuck commenced commercial operation in November 2020. PSE has no equity investment in Skookumchuck but is Skookumchuck’s only customer. Based on the terms of the contract, PSE will receive all of the output of the facility, subject to curtailment rights. PSE has concluded that Skookumchuck is a variable interest entity (VIE) and that PSE is not the primary beneficiary of this VIE since it does not control the commercial and operating activities of the facility. Additionally, PSE does not have the obligation to absorb losses or receive benefits. Therefore, PSE will not consolidate the VIE. Purchased energy of $7.2 million and $9.1 million were recognized in purchased electricity on the Company's consolidated statements of income for the six months ended June 30, 2022 and June 30, 2021, respectively. Additionally, $1.3 million and $2.7 million were included in accounts payable on the Company's balance sheet as of June 30, 2022 and December 31, 2021, respectively. On May 28, 2020, PSE entered into a PPA with Golden Hills Wind Farm, LLC (Golden Hills) pursuant to which Golden Hills would develop a wind generation facility and, once completed, sell bundled energy and associated attributes, namely RECs to PSE over a term of 20 years. On April 29, 2022, Golden Hills commenced commercial operations. PSE has no equity investment in Golden Hills but is Golden Hills’s only customer. Based on the terms of the contract, PSE will receive all of the output of the facility, subject to curtailment rights. PSE has concluded that Golden Hills is a VIE and that PSE is not the primary beneficiary of this VIE since it does not control the commercial and operating activities of the facility. Additionally, PSE does not have the obligation to absorb losses or receive benefits. Therefore, PSE will not consolidate the VIE. Purchased energy of $4.5 million was recognized in purchased electricity on the Company's consolidated statements of income for the six months ended June 30, 2022. Additionally, $2.5 million was included in accounts payable on the Company's balance sheet as of June 30, 2022.

New Accounting Pronouncements

New Accounting Pronouncements	6 Months Ended
	Jun. 30, 2022
Accounting Standards Update and Change in Accounting Principle [Abstract]
New Accounting Pronouncements	New Accounting Pronouncements Reference Rate Reform In March 2020, the FASB issued Accounting Standards Update (ASU) 2020-04, "Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting” (Issued March 2020). ASU 2020-04 provides temporary optional expedients and exceptions to the current guidance on contract modifications to ease the financial reporting burdens related to the expected market transition from London Interbank Offered Rate (LIBOR) and other interbank offered rates to alternative reference rates. The Company has promissory notes that reference LIBOR. As of June 30, 2022, the Company has not utilized any of the expedients discussed within this ASU; however, it continues to assess other agreements to determine if LIBOR is included and if the expedients would be utilized through the allowed period of December 2022.

Revenue

Revenue	6 Months Ended
	Jun. 30, 2022
Revenue from Contract with Customer [Abstract]
Revenue	Revenue The following tables present disaggregated revenue from contracts with customers, and other revenue by major source for the three months ended June 30, 2022 and June 30, 2021: Puget Energy and (Dollars in Thousands) Three Months Ended June 30, 2022 Revenue from contracts with customers: Electric Natural Gas Other Total Retail Residential $ 297,255 $ 159,200 $ — $ 456,455 Commercial 226,570 72,275 — 298,845 Industrial 27,711 5,121 — 32,832 Other 4,496 — — 4,496 Wholesale 24,061 — — 24,061 Transmission and transportation 10,633 5,088 — 15,721 Miscellaneous 4,019 53 11,991 16,063 Total revenue from contracts with customers $ 594,745 $ 241,737 $ 11,991 $ 848,473 Total other revenue 1 (414) (5,683) — (6,097) Total operating revenue $ 594,331 $ 236,054 $ 11,991 $ 842,376 _____________ 1 Total other revenue includes revenues from derivatives and alternative revenue programs that are not considered revenues from contracts with customers. Puget Energy and (Dollars in Thousands) Three Months Ended June 30, 2021 Revenue from contracts with customers: Electric Natural Gas Other Total Retail Residential $ 270,377 $ 121,124 $ — $ 391,501 Commercial 206,806 52,896 — 259,702 Industrial 25,843 4,235 — 30,078 Other 4,687 102 — 4,789 Wholesale 27,189 — — 27,189 Transmission and transportation 9,450 4,869 — 14,319 Miscellaneous 24,079 5,623 10,444 40,146 Total revenue from contracts with customers $ 568,431 $ 188,849 $ 10,444 $ 767,724 Total other revenue 1 (4,609) 6,275 — 1,666 Total operating revenue $ 563,822 $ 195,124 $ 10,444 $ 769,390 _____________ 1 Total other revenue includes revenues from derivatives, PTC deferral revenue and alternative revenue programs that are not considered revenues from contracts with customers. The following tables present disaggregated revenue from contracts with customers and other revenue by major source for the six months ended June 30, 2022 and June 30, 2021: Puget Energy and (Dollars in Thousands) Six Months Ended June 30, 2022 Revenue from contracts with customers: Electric Natural Gas Other 1 Total Retail Residential $ 713,515 $ 451,796 $ — $ 1,165,311 Commercial 483,589 193,254 — 676,843 Industrial 57,784 13,206 — 70,990 Other 9,257 — — 9,257 Wholesale 37,208 — — 37,208 Transmission and transportation 21,855 10,534 — 32,389 Miscellaneous 5,169 362 22,703 28,234 Total revenue from contracts with customers $ 1,328,377 $ 669,152 $ 22,703 $ 2,020,232 Total other revenue 2 22,331 (6,750) — 15,581 Total operating revenue $ 1,350,708 $ 662,402 $ 22,703 $ 2,035,813 _____________ 1 Other includes $0.1 million of Puget LNG revenues recorded at Puget Energy. 2 Total other revenue includes revenues from derivatives and alternative revenue programs that are not considered revenues from contracts with customers. Puget Energy and (Dollars in Thousands) Six Months Ended June 30, 2021 Revenue from contracts with customers: Electric Natural Gas Other Total Retail Residential $ 671,887 $ 397,811 $ — $ 1,069,698 Commercial 436,445 156,283 — 592,728 Industrial 53,376 11,770 — 65,146 Other 10,107 356 — 10,463 Wholesale 50,865 — — 50,865 Transmission and transportation 18,676 10,030 — 28,706 Miscellaneous 32,479 6,700 19,032 58,211 Total revenue from contracts with customers $ 1,273,835 $ 582,950 $ 19,032 $ 1,875,817 Total other revenue 1 48,579 5,080 — 53,659 Total operating revenue $ 1,322,414 $ 588,030 $ 19,032 $ 1,929,476 _____________ 1 Total other revenue includes revenues from derivatives and alternative revenue programs that are not considered revenues from contracts with customers. Transaction Price Allocated to Remaining Performance Obligations In December 2020, Puget LNG entered into a contract with one customer where Puget LNG is selling LNG over a 10-year delivery period beginning no later than 2024. The contract requires the customer to purchase a minimum annual quantity even if the customer does not take delivery. The price of the LNG includes a fixed charge, a fuel charge that includes both a market index and fixed margin component and other variable consideration. The fixed transaction price is allocated to the remaining performance obligations which is determined by the fixed charge components multiplied by the outstanding minimum annual quantity. Based on management’s best estimate of commencement, the Company expects to recognize this revenue over the following time periods: Puget Energy (Dollars in Thousands) 2024 2025 2026 2027 2028 Thereafter Total Remaining Performance Obligations $ 15,359 $ 19,710 $ 19,454 $ 19,454 $ 19,454 $ 102,135 $ 195,566

Accounting for Derivative Instr

Accounting for Derivative Instruments and Hedging Activities	6 Months Ended
	Jun. 30, 2022
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 power cost adjustment (PCA). Therefore, wholesale market transactions and PSE's related hedging strategies are focused on reducing costs and risks where feasible, thus, reducing volatility in costs in the portfolio. In order to manage its exposure to the variability in future cash flows for forecasted energy transactions, PSE utilizes a programmatic hedging strategy, which extends out three years. PSE's hedging strategy includes a risk-responsive component for the core natural gas portfolio, which utilizes quantitative risk-based measures with defined objectives to balance both portfolio risk and hedge costs. 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. Currently, the Company does not apply cash flow hedge accounting and therefore records all mark-to-market gains or losses through earnings. 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. The following table presents the volumes, fair values and classification of the Company's derivative instruments recorded on the balance sheets: Puget Energy and June 30, 2022 December 31, 2021 (Dollars in Thousands) Volumes (millions) Assets 1 Liabilities 2 Volumes (millions) Assets 1 Liabilities 2 Electric portfolio derivatives * $ 155,126 $ 43,073 * $ 74,829 $ 85,424 Natural gas derivatives (MMBtus) 3 319 123,915 20,518 347 79,578 18,850 Total derivative contracts $ 279,041 $ 63,591 $ 154,407 $ 104,274 Current $ 220,724 $ 53,177 $ 128,210 $ 63,309 Long-term 58,317 10,414 26,197 40,965 Total derivative contracts $ 279,041 $ 63,591 $ 154,407 $ 104,274 _______________ 1 Balance sheet classification: Current and Long-term Unrealized gain on derivative instruments. 2 Balance sheet classification: Current and Long-term Unrealized loss on derivative instruments. 3 All fair value adjustments on derivatives relating to the natural gas business have been deferred in accordance with ASC 980, “Regulated Operations,” due to the purchased gas adjustment (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 231.7 million British Thermal Units (MMBtu) and purchased electricity of 5.6 million at June 30, 2022, and 238.0 million MMBtus and 8.1 million MWhs at December 31, 2021. 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 natural gas and electric contracts; and North American Energy Standards Board (NAESB) agreements, which standardize physical natural 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 the 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. For further details regarding the fair value of derivative instruments, see Note 5, "Fair Value Measurements," to the consolidated financial statements included in Item 1 of this report. 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 At June 30, 2022 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 $ 279,041 $ — $ 279,041 $ (30,652) $ — $ 248,389 Liabilities: Energy derivative contracts $ 63,591 $ — $ 63,591 $ (30,652) $ (2,610) $ 30,329 Puget Energy and At December 31, 2021 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 $ 154,407 $ — $ 154,407 $ (40,833) $ — $ 113,574 Liabilities: Energy derivative contracts $ 104,274 $ — $ 104,274 $ (40,833) $ (1,743) $ 61,698 _______________ 1 All derivative contract deals are executed under ISDA, NAESB, and WSPP master agreements with right of set-off. The following table presents the effect and classification of the realized and unrealized gains (losses) of the Company's derivatives recorded on the statements of income: Puget Energy and Three Months Ended Six Months Ended (Dollars in Thousands) Classification 2022 2021 2022 2021 Gas for power derivatives: Unrealized Unrealized gain (loss) on derivative instruments, net $ (16,582) $ 51,241 $ 70,291 $ 52,869 Realized Electric generation fuel 16,039 2,785 43,130 11,098 Power derivatives: Unrealized Unrealized gain (loss) on derivative instruments, net 7,309 10,035 52,357 31,409 Realized Purchased electricity 4,454 6,287 7,045 (7,016) Total gain (loss) recognized in income on derivatives $ 11,220 $ 70,348 $ 172,823 $ 88,360 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, and exposure monitoring and mitigation. The Company monitors counterparties for significant swings in credit default swap rates, credit rating changes by external rating agencies, ownership changes or 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, 2022, approximately 99.4% of the Company's energy portfolio exposure, excluding normal purchase normal sale (NPNS) transactions, is with counterparties that are rated investment grade by rating agencies and 0.6% are either rated below investment grade or not rated by rating agencies. The Company assesses credit risk internally for counterparties that are not rated by the major rating agencies. The Company computes credit reserves at a master agreement level by counterparty. The Company considers external credit ratings and market factors in the determination of reserves, such as credit default swaps and bond spreads. 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 determined 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 netted against the unrealized gain (loss) positions. The majority of the Company's derivative contracts are with financial institutions and other utilities operating within the Western Electricity Coordinating Council. PSE also transacts power futures contracts on the Intercontinental Exchange (ICE), and natural gas contracts on the ICE natural gas exchange (NGX) platform. Execution of contracts on ICE requires the daily posting of margin calls as collateral through a futures and clearing agent. As of June 30, 2022, PSE had cash posted as collateral of $4.2 million related to contracts executed on the ICE platform, as well as $9.0 million in cash posted as collateral and no letter of credit posted as a condition of transacting on the ICE NGX platform. 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 during the three months ended June 30, 2022. The following table presents the aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position and the amount of additional collateral the Company could be required to post: Puget Energy and (Dollars in Thousands) At June 30, 2022 At December 31, 2021 Fair Value 1 Posted Contingent Fair Value 1 Posted Contingent Contingent Feature Liability Collateral Collateral Liability Collateral Collateral Credit rating 2 $ 16,686 $ — $ 16,686 $ 52,537 $ — $ 52,537 Requested credit for adequate assurance 8,186 — — 9,380 — — Forward value of contract 3 2,610 4,228 N/A 1,743 12,782 N/A Total $ 27,482 $ 4,228 $ 16,686 $ 63,660 $ 12,782 $ 52,537 _______________ 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, 2022
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 as substantially all assumptions and inputs are observable in active markets throughout the full term of the instruments. On a daily basis, the Company obtains quoted forward prices for the electric and natural gas markets from an independent external pricing service. The Company considers its electric and natural gas contracts as Level 2 derivative instruments as such contracts are commonly traded as over-the-counter forwards with indirectly observable price quotes. However, certain energy derivative instruments with maturity dates falling outside the range of observable price quotes or that are transacted at illiquid delivery locations are classified as Level 3 in the fair value hierarchy. Management's assessment is 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 used to value Level 2 commodity contracts with the actual prices of commodity contracts entered into during the most recent quarter. Assets and Liabilities with Estimated Fair Value The carrying values of cash and cash equivalents, restricted cash, and short-term debt as reported on the balance sheet are reasonable estimates of their fair value due to the short-term nature of these instruments and are classified as Level 1 in the fair value hierarchy. The carrying value of other investments of $54.5 million and $53.2 million at June 30, 2022 and December 31, 2021 respectively, are included in "Other property and investments" on the balance sheet. These values are also reasonable estimates of their fair value and classified as Level 2 in the fair value hierarchy as they are valued based on market rates for similar transactions. The fair value of the long-term notes was estimated using the discounted cash flow method with the U.S. Treasury yields and the Company's credit spreads as inputs, interpolating to the maturity date of each issue. The carrying values and estimated fair values were as follows: Puget Energy June 30, 2022 December 31, 2021 (Dollars in Thousands) Level Carrying Fair Carrying Fair Liabilities: Long-term debt (fixed-rate), net of discount 1 2 $ 6,622,901 $ 6,556,096 $ 6,170,466 $ 7,769,896 Long-term debt (variable-rate) 2 34,300 34,300 33,300 33,300 Total liabilities $ 6,657,201 $ 6,590,396 $ 6,203,766 $ 7,803,196 Puget Sound Energy June 30, 2022 December 31, 2021 (Dollars in Thousands) Level Carrying Fair Carrying Fair Liabilities: Long-term debt (fixed-rate), net of discount 2 2 $ 4,785,752 $ 4,710,369 $ 4,784,719 $ 6,145,639 Total liabilities $ 4,785,752 $ 4,710,369 $ 4,784,719 $ 6,145,639 _______________ 1 The carrying value includes debt issuances costs of $22.5 million and $22.7 million for June 30, 2022 and December 31, 2021, respectively, which are not included in fair value. 2 The carrying value includes debt issuances costs of $22.1 million and $22.8 million for June 30, 2022 and December 31, 2021, respectively, which are not included in fair value. Assets and Liabilities Measured at Fair Value on a Recurring Basis The following table presents 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 and Fair Value Fair Value (Dollars in Thousands) Level 2 Level 3 Total Level 2 Level 3 Total Assets: Electric derivative instruments $ 135,724 $ 19,403 $ 155,127 $ 68,011 $ 6,818 $ 74,829 Natural gas derivative instruments 123,158 756 123,914 79,526 52 79,578 Total assets $ 258,882 $ 20,159 $ 279,041 $ 147,537 $ 6,870 $ 154,407 Liabilities: Electric derivative instruments $ 29,585 $ 13,487 $ 43,072 $ 35,854 $ 49,570 $ 85,424 Natural gas derivative instruments 19,046 1,473 20,519 16,678 2,172 18,850 Total liabilities $ 48,631 $ 14,960 $ 63,591 $ 52,532 $ 51,742 $ 104,274 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, (Dollars in Thousands) 2022 2021 Level 3 Roll-Forward Net Asset/(Liability) Electric Natural Gas Total Electric Natural Gas Total Balance at beginning of period $ (6,010) $ (1,212) $ (7,222) $ (21,170) $ (1,834) $ (23,004) Changes during period: Realized and unrealized energy derivatives: Included in earnings 1 4,814 — 4,814 14,690 — 14,690 Included in regulatory assets / liabilities — 70 70 — (195) (195) Settlements 7,018 271 7,289 132 167 299 Transferred into Level 3 — — — — — — Transferred out of Level 3 94 154 248 — — — Balance at end of period $ 5,916 $ (717) $ 5,199 $ (6,348) $ (1,862) $ (8,210) Puget Energy and Six Months Ended June 30, (Dollars in Thousands) 2022 2021 Level 3 Roll-Forward Net Asset/(Liability) Electric Natural Gas Total Electric Natural Gas Total Balance at beginning of period $ (42,752) $ (2,120) $ (44,872) $ (23,718) $ (1,135) $ (24,853) Changes during period: Realized and unrealized energy derivatives: Included in earnings 2 43,633 — 43,633 15,510 — 15,510 Included in regulatory assets / liabilities — 485 485 — (1,083) (1,083) Settlements 4,766 595 5,361 1,860 356 2,216 Transferred into Level 3 — — — — — — Transferred out of Level 3 269 323 592 — — — Balance at end of period $ 5,916 $ (717) $ 5,199 $ (6,348) $ (1,862) $ (8,210) _______________ 1 Income Statement locations: Unrealized (gain) loss on derivative instruments, net. Amounts include unrealized gains (losses) on derivatives still held in position as of the reporting date for electric derivatives of $4.6 million and $14.8 million for three months ended June 30, 2022 and 2021, respectively. 2 Income Statement locations: Unrealized (gain) loss on derivative instruments, net. Amounts include unrealized gains (losses) on derivatives still held in position as of the reporting date for electric derivatives of $40.8 million and $15.6 million for six months ended June 30, 2022 and 2021, respectively. 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. 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. The weighted average price is calculated as the total market value divided by the total volume of the Company's Level 3 electric and gas commodity contracts, respectively, as of the reporting date. The following table presents the forward price ranges for the Company's Level 3 commodity contracts as of June 30, 2022: Puget Energy and Fair Value Range (Dollars in Thousands) Assets 1 Liabilities 1 Valuation Technique Unobservable Input Low High Weighted Average Electric $ 19,403 $ (13,487) Discounted cash flow Power prices (per MWh) $ 33.76 $ 136.57 $ 81.03 Natural gas $ 756 $ (1,473) Discounted cash flow Natural gas prices (per MMBtu) $ 4.48 $ 6.36 $ 5.33 _______________ 1 The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions. The following table presents the forward price ranges for the Company's Level 3 commodity contracts as of December 31, 2021: Puget Energy and Fair Value Range (Dollars in Thousands) Assets 1 Liabilities 1 Valuation Technique Unobservable Input Low High Weighted Average Electric $ 6,818 $ 49,570 Discounted cash flow Power prices (per MWh) $ 21.88 $ 119.38 $ 61.51 Natural gas $ 52 $ 2,172 Discounted cash flow Natural gas prices (per MMBtu) $ 3.65 $ 7.54 $ 5.89 ___________ 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. As of June 30, 2022, and December 31, 2021, 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 $20.3 million and $17.9 million, respectively. Long-Lived Assets Measured at Fair Value on a Nonrecurring Basis Puget Energy records the fair value of its intangible assets in accordance with ASC 360, “Property, Plant, and Equipment,” (ASC 360). The fair value assigned to the power contracts was determined using an income approach comparing the contract rate to the market rate for power over the remaining period of the contracts incorporating non-performance risk. Management also incorporated certain assumptions related to quantities and market presentation that it believes market participants would make in the valuation. The fair value of the power contracts is amortized as the contracts settle. ASC 360 requires long-lived assets to be tested for recoverability whenever events or changes in circumstances indicate that its carrying amount may not be recoverable. One such triggering event is a significant decrease in the forward market prices of power. As of June 30, 2022, Puget Energy completed valuation and impairment testing of its power purchase contracts classified as intangible assets and determined that no impairment was needed. These intangible assets exist as a result of the merger in 2009, at which time the consolidated assets and liabilities were revalued in accordance with ASC 805, "Business Combinations."

Retirement Benefits

Retirement Benefits	6 Months Ended
	Jun. 30, 2022
Subsidiaries [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Benefits Disclosure [Text Block]	Retirement Benefits PSE has a defined benefit pension plan (Qualified Pension Benefits) covering a substantial majority of PSE employees. For employees hired prior to 2014, 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. Effective January 1, 2014, all new UA represented employees hired or rehired receive annual pay credits of 4.0% of eligible pay each year in the cash balance formula of the defined pension plan. Effective January 1, 2014 for non-represented employees, and December 12, 2014 for employees represented by the IBEW, newly hired or rehired employees receive annual employer contributions of 4.0% of eligible pay each year into the cash balance formula of the defined benefit pension or 401k plan account. PSE also has a non-qualified Supplemental Executive Retirement Plan (SERP) for certain key senior management employees that closed to new participants in 2019. Effective 2019, PSE has an officer restoration benefit for new officers who join PSE or are promoted, such that company contributions under PSE’s applicable tax-qualified plan, which otherwise would have been credited if not for the IRS limitations, are credited at 4.0% of earnings to an account with the Deferred Compensation Plan. In addition to providing pension benefits, PSE provides legacy group health care and life insurance benefits (Plan) 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 prior year. On June 11, 2019, the Company's Welfare Benefits Committee approved the termination of the Plan effective December 31, 2019, and the creation of a Retiree Health Reimbursement Account (HRA) Plan effective January 1, 2020. Puget Energy's retirement plans were remeasured as a result of the merger in 2009, which represents the difference between Puget Energy and PSE's retirement plans. The components of service cost are included within utility operations and maintenance for PSE and within non-utility expense and other for Puget Energy while all non-service cost components are included in other income. For further information, see Note 13, "Retirement Benefits" to the consolidated financial statements included in Item 8 of the Company's Form 10-K for the period ended December 31, 2021. The following tables summarize the Company’s net periodic benefit cost for the three and six months ended June 30, 2022 and 2021: Puget Energy Qualified SERP Other Three Months Ended June 30, (Dollars in Thousands) 2022 2021 2022 2021 2022 2021 Components of net periodic benefit cost: Service cost $ 6,378 $ 6,733 $ 139 $ 115 $ 55 $ 41 Interest cost 6,044 5,613 313 293 81 77 Expected return on plan assets (12,730) (12,039) — — (99) (91) Amortization of prior service cost — (476) 72 87 6 2 Amortization of net loss (gain) 1,563 3,072 618 588 (4) (10) Net periodic benefit cost $ 1,255 $ 2,903 $ 1,142 $ 1,083 $ 39 $ 19 Puget Energy Qualified SERP Other Six Months Ended June 30, (Dollars in Thousands) 2022 2021 2022 2021 2022 2021 Components of net periodic benefit cost: Service cost $ 13,175 $ 13,444 $ 279 $ 229 $ 109 $ 82 Interest cost 12,131 11,191 626 586 163 154 Expected return on plan assets (25,507) (24,120) — — (198) (183) Amortization of prior service cost — (952) 145 174 11 3 Amortization of net loss (gain) 3,191 5,901 1,236 1,175 (8) (20) Net periodic benefit cost $ 2,990 $ 5,464 $ 2,286 $ 2,164 $ 77 $ 36 Puget Sound Energy Qualified SERP Other Three Months Ended June 30, (Dollars in Thousands) 2022 2021 2022 2021 2022 2021 Components of net periodic benefit cost: Service cost $ 6,378 $ 6,733 $ 139 $ 115 $ 55 $ 41 Interest cost 6,044 5,613 313 293 81 77 Expected return on plan assets (12,730) (12,040) — — (98) (91) Amortization of prior service cost — (378) 72 87 6 2 Amortization of net loss (gain) 3,734 5,620 662 635 (6) (14) Net periodic benefit cost $ 3,426 $ 5,548 $ 1,186 $ 1,130 $ 38 $ 15 Puget Sound Energy Qualified SERP Other Six Months Ended June 30, (Dollars in Thousands) 2022 2021 2022 2021 2022 2021 Components of net periodic benefit cost: Service cost $ 13,175 $ 13,444 $ 279 $ 229 $ 109 $ 82 Interest cost 12,131 11,191 626 586 163 154 Expected return on plan assets (25,508) (24,121) — — (197) (183) Amortization of prior service cost — (756) 145 174 11 3 Amortization of net loss (gain) 7,540 10,931 1,324 1,271 (11) (28) Net periodic benefit cost $ 7,338 $ 10,689 $ 2,374 $ 2,260 $ 75 $ 28 The following table summarizes the Company’s change in benefit obligation for the periods ended June 30, 2022 and December 31, 2021: Puget Energy and Qualified SERP Other Six Months Ended Year Ended Six Months Ended Year Ended Six Months Ended Year Ended (Dollars in Thousands) June 30, December 31, June 30, December 31, June 30, December 31, Change in benefit obligation: Benefit obligation at beginning of period $ 834,960 $ 849,383 $ 43,155 $ 46,742 $ 11,654 $ 12,114 Amendments — — — — — 205 Service cost 13,175 26,888 279 456 109 155 Interest cost 12,131 22,381 626 1,183 163 302 Actuarial loss (gain) (1,440) (6,826) — 828 — (514) Benefits paid (24,948) (55,831) (990) (6,054) (452) (803) Medicare part D subsidy received — — — — — 195 Administrative Expense — (1,035) — — — — Benefit obligation at end of period $ 833,878 $ 834,960 $ 43,070 $ 43,155 $ 11,474 $ 11,654 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, 2022, are expected to be at least $18.0 million, $2.8 million and $0.3 million, respectively. The Company contributed $1.0 million to fund the SERP during the six months ended June 30, 2022 and 2021. The Company contributed an immaterial amount to fund the other postretirement plans.

Regulation and Rates

Regulation and Rates	6 Months Ended
	Jun. 30, 2022
Subsidiaries [Member]
Entity Information [Line Items]
Regulation and Rates Disclosure	Regulation and Rates General Rate Case PSE filed a general rate case (GRC) which includes a three year multiyear rate plan with the Washington Commission on January 31, 2022, requesting an overall increase in electric and natural gas rates of 13.6% and 13.0% respectively in 2023; 2.5% and 2.3%, respectively in 2024; and 1.2% and 1.8%, respectively, in 2025. PSE requested a return on equity of 9.9% in all three-rate years. PSE requested an overall rate of return of 7.39% in 2023; 7.44% in 2024; and 7.49% in 2025. The filing requests recovery of forecasted plant additions through 2022 as required by Revised Code of Washington 80.28.425 as well as forecasted plant additions through 2025, the final year of the multiyear rate plan. The Washington Commission issued a procedural schedule and the case is pending. The Company cannot predict the outcome of the case at this time. PSE filed a GRC with the Washington Commission on June 20, 2019 requesting an overall increase in electric and natural gas rates of 6.9% and 7.9% respectively. On July 8, 2020, the Washington Commission issued its order on PSE’s GRC. The ruling provided for a weighted cost of capital of 7.39% or 6.8% after-tax, and a capital structure of 48.5% in common equity with a return on equity of 9.4%. The order also resulted in a combined net increase to electric of $29.5 million, or 1.6%, and to natural gas of $36.5 million, or 4.0%. However, the Washington Commission extended the amortization of certain regulatory assets, PSE’s electric decoupling deferral, and PSE’s PGA deferral to mitigate the impact of the rate increase in response to the economic instability created by the COVID-19 pandemic. This reduced the electric revenue increase to approximately $0.9 million, or 0.05%, and the natural gas increase to $1.3 million, or 0.15%, and became effective October 15, 2020 and October 1, 2020, respectively. On July 30, 2021, the IRS issued a Private Letter Ruling (PLR) to PSE which concluded that in the 2019 GRC the Washington Commission’s methodology for reversing plant-related excess deferred income taxes was an impermissible methodology under the IRS normalization and consistency rules. The PLR required adjustments to PSE's rates to bring PSE back into compliance with IRS rules. Accordingly, on September 28, 2021, the Washington Commission issued an order amending their order previously issued on July 8, 2020, to correct for items which were determined to be impermissible under IRS normalization and consistency rules as detailed in the PLR. To reflect the impact of the PLR, PSE recorded a regulatory asset and additional revenues of $24.5 million in its operating results through December 31, 2021. The annualized overall rate impact was an increase of $15.8 million, or 0.7%, for electric and $3.1 million, or 0.3%, for natural gas for a total of $18.9 million with rates effective October 1, 2021. This led to a combined annualized net increase to electric rates of $77.1 million, or 3.7%, an increase of $17.5 million above the $59.6 million granted in the revised final order. The order also led to a combined annualized net increase to natural gas rates of $45.3 million, or 5.9%, an increase of $2.4 million above the $42.9 million granted in the revised final order. The Washington Commission maintained adjustments that mitigated the impacts of the rate increases in response to the economic instability created by the COVID-19 pandemic, which reduced the electric revenue increase to approximately $48.3 million, or 2.3%, and the natural gas increase to $4.9 million, or 0.6%. Power Cost Only Rate Case On December 9, 2020, PSE filed its 2020 power cost only rate case (PCORC). The filing proposed an increase of $78.5 million (or an average of approximately 3.7%) in the Company's overall power supply costs with an anticipated effective date in June 2021. On February 2, 2021, PSE supplemented the PCORC to update its power costs, leading to a requested increase from $78.5 million to $88.0 million (or an average of approximately 4.1%). On March 2, 2021, several of the parties to the PCORC reached a multiparty settlement in principle, which was unopposed. The settlement resulted in an estimated revenue increase of $65.3 million or 3.1%. A term of the settlement requires PSE to include in its next GRC (or another proceeding in 2022) the issue of whether the PCORC should continue, and further prohibits PSE from filing another PCORC before this issue is litigated. On June 1, 2021, the Washington Commission issued its Final Order approving and adopting the settlement and authorizing and requiring a power cost update through a compliance filing. On June 17, 2021, PSE filed a compliance filing with the Washington Commission with a revenue increase of $70.9 million or 3.3% due to the update on power costs with rates effective July 1, 2021. Decoupling Filings On July 8, 2020, the Washington Commission issued the final order in Dockets UE-190529 and UG-190530, which instructed PSE to extend the collection of amortization balances for electric decoupling delivery and fixed power cost sections originally filed through the annual May 2020 decoupling filing. The extension requires PSE to move amortization balances for electric decoupling as of August 31, 2020 to be collected from customers for a two-year period, instead of the originally approved one-year period. Additionally, through approving the electric cost of service, the final order approved the re-allocation of decoupling balances from Schedule 40 to the remaining electric decoupling groups. On December 23, 2020, the Washington Commission approved PSE’s filing to update Schedule 142 decoupling amortization rates, with an effective date of January 1, 2021, by zeroing out rates still effective past October 15, 2020 on tariff sheet Schedule 142-H, which was replaced by rates on tariff sheet Schedule 142-I effective October 15, 2020. PSE included a true up of the over-collection amounts for the period of October 15, 2020 through December 31, 2020 in PSE’s annual May 2021 decoupling filing. On June 1, 2021, the Washington Commission approved the multi-party settlement agreement which was filed within PSE’s PCORC filing. As part of this settlement agreement, the electric annual fixed power cost allowed revenue was updated to reflect changes in the approved revenue requirement. The changes took effect on July 1, 2021. On September 28, 2021, the Washington Commission approved 2019 GRC filing updated to PLR changes. As part of this filing, the annual electric and gas delivery cost allowed revenue was updated to reflect changes in the approved revenue requirement. The changes took effect on October 1, 2021. On June 30, 2022, PSE performed an analysis to determine if electric and natural gas decoupling revenue deferrals would be collected from customers within 24 months of the annual period, per ASC 980. If not, for GAAP purposes only, PSE would need to record a reserve against the decoupling revenue and corresponding regulatory asset balance. Once the reserve is probable of collection within 24 months from the end of the annual period, the reserve can be recognized as decoupling revenue. The analysis indicated that electric and natural gas deferred revenue will be collected within 24 months of the annual period; therefore, no reserve adjustment was booked to 2022 electric or natural gas decoupling revenue. At June 30, 2021, the analysis estimated $0.8 million of electric deferred revenue not to be collected within 24 months of the annual period in 2021; therefore, a reserve adjustment was booked to 2021 electric decoupling revenue. At June 30, 2021, natural gas deferred revenue was estimated to be collected within 24 months of the annual period in 2021; therefore, no reserve adjustment was booked to 2021 natural gas decoupling revenue. Power Cost Adjustment Mechanism PSE currently has a PCA mechanism that provides for the deferral of power costs that vary from the “power cost baseline” level of power costs. The “power cost baseline” levels are set, in part, based on normalized assumptions about weather and hydroelectric conditions. Excess power costs or savings are apportioned between PSE and its customers pursuant to the graduated scale set forth in the PCA mechanism and will trigger a surcharge or refund when the cumulative deferral trigger is reached. Effective January 1, 2017, the following graduated scale is used in the PCA mechanism: Company’s Share Customers' Share Annual Power Cost Variability Over Under Over Under Over or Under Collected by up to $17 million 100 % 100 % — % — % Over or Under Collected by between $17 million - $40 million 35 50 65 50 Over or Under Collected beyond $40 + million 10 10 90 90 For the six months ended June 30, 2022, in its PCA mechanism, PSE under recovered its allowable costs by $26.6 million of which $4.8 million was apportioned to customers and $0.6 million of interest was accrued on the deferred customer balance. This compares to an under recovery of allowable costs of $30.5 million for the six months ended June 30, 2021, of which $6.7 million was apportioned to customers and accrued $0.7 million of interest on the total deferred customer balance. Power Cost Adjustment Clause Filing On July 8, 2020, the Washington Commission issued the final order in Dockets UE-190529 and UG-190530, which instructed PSE to remove Schedule 95 collection on decoupling allowed rates for Microsoft Special Contracts, which will be included in allowed rates under the Decoupling Schedule 142 effective October 15, 2020. PSE exceeded the $20.0 million cumulative deferral balance in its PCA mechanism in 2020. The surcharging of deferrals can be triggered by the Company when the balance in the deferral account is a credit of $20.0 million or more. During 2020, actual power costs were higher than baseline power costs; thereby, creating an under-recovery of $76.1 million. Under the terms of the PCA’s sharing mechanism for under-recovered power costs, PSE absorbed $32.1 million of the under-recovered amount, and customers were responsible for the remaining $44.0 million, or $46.0 million including interest. PSE filed to recover the deferred balance in Docket UE-210300, and the Washington Commission allowed the recovery effective December 1, 2021. Additionally, PSE exceeded the $20.0 million cumulative deferral balance in its PCA mechanism in 2021. During 2021, actual power costs were higher than baseline power costs; thereby, creating an under-recovery of $68.0 million. Under the terms of the PCA’s sharing mechanism for under-recovered power costs, PSE absorbed $31.3 million of the under-recovered amount, and customers were responsible for the remaining $36.7 million, or $38.4 million including interest. On April 29, 2022, PSE filed a 2021 PCA report with the Washington Commission that proposes to recover the deferred balance for 2021 PCA period by keeping the current rates and allowing recovery from January 1, 2023 through November 30, 2023. Purchased Gas Adjustment Mechanism On October 28, 2021, the Washington Commission approved PSE's request for November 2021 PGA rates in Docket UG-210721, effective November 1, 2021. As part of that filing, PSE requested an annual revenue increase of $59.1 million; where PGA rates, under Schedule 101, increase annual revenue by $80.6 million, and the tracker rates under Schedule 106, decrease annual revenue by $21.5 million. Those annual 2021 PGA rate increases will be set in addition to continuing the collection on the remaining balance of $69.4 million under Supplemental Schedule 106B, which were set, in effect, through September 30, 2023 per the 2019 GRC. The following table presents the PGA mechanism balances and activity at June 30, 2022 and December 31, 2021: (Dollars in Thousands) At June 30, At December 31, PGA receivable balance and activity 2022 2021 PGA receivable beginning balance $ 57,935 $ 87,655 Actual natural gas costs 263,404 364,775 Allowed PGA recovery (267,514) (396,236) Interest 709 1,741 PGA receivable ending balance $ 54,534 $ 57,935 Get to Zero Depreciation Deferral On April 10, 2019, PSE filed an accounting petition with the Washington Commission, requesting authorization to defer depreciation expense associated with Get to Zero (GTZ) projects that were placed in service after June 30, 2018. The GTZ project consists of a number of short-lived technology upgrades. The depreciation expense associated with the GTZ projects with lives of 10 years or less that were placed in service after June 30, 2018, were deferred beginning May 1 per the petition request. At June 30, 2022 and December 31, 2021, PSE deferred $9.2 million and $6.6 million of depreciation expense for GTZ, respectively. In addition to the deferral of depreciation expense, PSE had also requested to defer carrying charges on the GTZ deferral, to be calculated utilizing the Company’s currently authorized after tax rate of return, or 6.89%. The ruling authorized PSE to amortize deferred GTZ expenses as proposed in the original GRC filing. The ruling also allows continued deferral of the depreciation expense associated with GTZ investments not already approved for recovery with a book life of 10 years or less, through PSE's then-next GRC, which PSE filed on January 31, 2022, and is currently pending. Finally, the final order set the rate at which PSE could defer and recover carrying charges from PSE’s authorized rate of return to the quarterly interest rate established by the FERC. Crisis Affected Customer Assistance Program On April 6, 2020, PSE filed with the Washington Commission revisions to its currently effective electric and natural gas service tariffs. The purpose of this filing was to incorporate into PSE’s low-income tariff a new temporary bill assistance program, Crisis Affected Customer Assistance Program (CACAP-1) (dockets UE-200331 and UG-200332), to mitigate the economic impact of the COVID-19 pandemic on PSE’s customers. CACAP-1 would allow PSE customers facing financial hardship due to COVID-19 to receive up to $1,000 in bill assistance. The program made available $11.0 million in unspent low income funds from prior years, therefore resulting in no rate impact, and supplemented other forms of financial assistance. CACAP-1 ran from April 13, 2020, to September 30, 2020. On March 28, 2021, the Washington Commission approved PSE’s CACAP-2 (dockets UE-210137 and UG-210138). With a program budget of $20.0 million for electric customers and $7.7 million for natural gas customers, CACAP-2, which ran from April 12, 2021, to March 29, 2022, would provide up to $2,500 in bill assistance in arrearages per year for each qualifying low-income household. On October 15, 2021, PSE submitted for the Washington Commission’s review and approval a Supplemental CACAP (dockets UE-210792 and UG-210793) filing to continue assistance for PSE customers facing financial hardship due to COVID-19. The Washington Commission approved the Supplemental CACAP program to be effective on November 15, 2021. The Supplemental CACAP would utilize carry-over funds not expended in any prior years under PSE’s Schedule 129 Home Energy Lifeline Program (HELP), with a combined total budget of $34.5 million for both electric and natural gas residential customers (capped at $23.7 million and $10.8 million, respectively). Supplemental CACAP benefits would cover a qualifying residential customer’s past due balance, up to $2,500. PSE applied the Supplemental CACAP benefits automatically, with an opt-out option, in December 2021.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Disclosure	Commitments and Contingencies Colstrip PSE has a 50% ownership interest in Colstrip Units 1 and 2 and a 25% interest in each of Colstrip Units 3 and 4, which are coal-fired generating units located in Colstrip, Montana. PSE has accelerated the depreciation of Colstrip Units 3 and 4 to December 31, 2025 as part of the 2019 GRC. The 2017 GRC repurposed PTCs and hydro-related treasury grants to recover unrecovered plant costs and to fund and recover decommissioning and remediation costs for Colstrip Units 1 through 4. Consistent with a June 2019 announcement, Talen permanently shut down Units 1 and 2 at the end of 2019 due to operational losses associated with the Units. Colstrip Units 1 and 2 were retired effective December 31, 2019. The Washington Clean Energy Transformation Act requires the Washington Commission to provide recovery of the investment, decommissioning, and remediation costs associated with the facilities that are not recovered through the repurposed PTCs and hydro-related treasury grants. The full scope of decommissioning activities and costs may vary from the estimates that are available at this time. On May 19, 2021, PSE along with the Colstrip owners, Avista Corporation, PacifiCorp and Portland General Electric Company filed a lawsuit against the Montana Attorney General challenging the constitutionality of Senate Bill 266. On October 13, 2021, the United States District Court for the District of Montana issued a preliminary injunction finding it likely that Senate Bill 266 unconstitutionally violates the Commerce Clause and Contract Clause of the United States Constitution. Since then, a motion for summary judgment was filed requesting a permanent injunction against enforcement of Senate Bill 266. As of June 30, 2022, the Company is not able to predict the outcome, nor an amount or range of potential impact in the event of an outcome that is adverse to the Company’s interests. Other Commitments and Contingencies There have been no material changes to the contractual obligations and consolidated commercial commitments disclosed in Part II, Item 8, Note 16, "Commitments and Contingencies" in the Company's Annual Report on Form 10-K for the year ended December 31, 2021.

Leases (Notes)

Leases (Notes)	6 Months Ended
	Jun. 30, 2022
Leases [Abstract]
Leases	LeasesAs of June 30, 2022, there have been no material changes regarding the Company's leases. For further information, see Part II, Item 8, Note 9, "Leases" in the Company’s Annual Report on Form 10-K for the year ended December 31, 2021
Leases	LeasesAs of June 30, 2022, there have been no material changes regarding the Company's leases. For further information, see Part II, Item 8, Note 9, "Leases" in the Company’s Annual Report on Form 10-K for the year ended December 31, 2021

Other

Other	6 Months Ended
	Jun. 30, 2022
Other [Abstract]
Other	Other Long-Term Debt On June 14, 2021, Puget Energy issued $500.0 million of senior secured notes at an interest rate of 2.379%. The notes mature on June 15, 2028, and pay interest semi-annually on June 15 and December 15. Proceeds from the issuance of the notes were invested in short-term money market funds, and then used to repay the Company’s $500.0 million 6.00% notes that matured on September 1, 2021. On June 23, 2021, Puget Energy received an equity contribution from Puget Equico, LLC, Puget Energy’s parent company. The proceeds from the equity contribution were used to pay off Puget Energy’s $210.0 million term loan. On September 15, 2021, PSE issued $450.0 million of senior secured notes at an interest rate of 2.893%. The notes mature on September 15, 2051, and pay interest semi-annually on March 15 and September 15 of each year. The proceeds from the issuance were used for repayment of commercial paper as well as general corporate purposes. On March 17, 2022, Puget Energy issued $450.0 million of senior secured notes at an interest rate of 4.224%. The notes mature on March 15, 2032, and pay interest semi-annually on March 15 and September 15 of each year. Proceeds from the issuance of the notes were invested in short-term money market funds, and then used to repay Puget Energy's $450.0 million 5.625% notes that were originally scheduled to mature July 2022.
Short-term Debt	Short-Term Debt As of June 30, 2022, no amount was drawn under PSE's credit facility and $55.0 million was outstanding under the commercial paper program at PSE. For further information, see Part II, Item 8, Note 8, "Liquidity Facilities and Other Financing Arrangements" in the Company's Annual Report on Form 10-K for the year ended December 31, 2021.
Credit Facilities	Credit Facilities On May 16, 2022, Puget Energy entered into an $800.0 million credit facility to replace the existing facility. The terms and conditions, including fees, financial covenant, expansion feature and credit spreads remain substantially the same. The base interest rate on loans has changed to the Secured Overnight Funding Rate (SOFR), as the LIBOR is being discontinued in 2023. The proceeds of the PE credit facility are to be used for general corporate purposes. The maturity date of the credit facility is May 14, 2027. As of June 30, 2022, $43.3 million was drawn and outstanding under the facility, of which $34.3 million was classified as long-term debt and $9.0 million was classified as short-term debt. On May 16, 2022, PSE entered into an $800.0 million credit facility to replace the existing facility. The terms and conditions, including fees, financial covenant, expansion feature and credit spreads remain substantially the same. The base interest rate on loans has changed to the SOFR, as the LIBOR is being discontinued in 2023. The proceeds of the PSE credit facility are to be used for general corporate purposes. The maturity date of the credit facility is May 14, 2027. As of June 30, 2022, no amount was drawn under PSE's credit facility. For further information, see Part II, Item 8, Note 7, "Long-Term Debt" and Note 8, "Liquidity Facilities and Other Financing Arrangements" in the Company's Annual Report on Form 10-K for the year ended December 31, 2021.

Summary of Consolidation and _2

Summary of Consolidation and Significant Accounting Policy (Tables)	6 Months Ended
	Jun. 30, 2022
Accounting Policies [Abstract]
Accounts Receivable, Allowance for Credit Loss	The following table presents the activity in the allowance for credit losses for accounts receivable for the six months ended June 30, 2022 and 2021: Puget Energy and Six Months (Dollars in Thousands) 2022 2021 Allowance for credit losses: Beginning balance $ 34,958 $ 20,080 Provision for credit loss expense 1 15,727 18,421 Receivables charged-off (8,343) (5,060) Total ending allowance balance $ 42,342 $ 33,441 _______________ 1

Revenue (Tables)

Revenue (Tables)	6 Months Ended
	Jun. 30, 2022
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following tables present disaggregated revenue from contracts with customers, and other revenue by major source for the three months ended June 30, 2022 and June 30, 2021: Puget Energy and (Dollars in Thousands) Three Months Ended June 30, 2022 Revenue from contracts with customers: Electric Natural Gas Other Total Retail Residential $ 297,255 $ 159,200 $ — $ 456,455 Commercial 226,570 72,275 — 298,845 Industrial 27,711 5,121 — 32,832 Other 4,496 — — 4,496 Wholesale 24,061 — — 24,061 Transmission and transportation 10,633 5,088 — 15,721 Miscellaneous 4,019 53 11,991 16,063 Total revenue from contracts with customers $ 594,745 $ 241,737 $ 11,991 $ 848,473 Total other revenue 1 (414) (5,683) — (6,097) Total operating revenue $ 594,331 $ 236,054 $ 11,991 $ 842,376 _____________ 1 Total other revenue includes revenues from derivatives and alternative revenue programs that are not considered revenues from contracts with customers. Puget Energy and (Dollars in Thousands) Three Months Ended June 30, 2021 Revenue from contracts with customers: Electric Natural Gas Other Total Retail Residential $ 270,377 $ 121,124 $ — $ 391,501 Commercial 206,806 52,896 — 259,702 Industrial 25,843 4,235 — 30,078 Other 4,687 102 — 4,789 Wholesale 27,189 — — 27,189 Transmission and transportation 9,450 4,869 — 14,319 Miscellaneous 24,079 5,623 10,444 40,146 Total revenue from contracts with customers $ 568,431 $ 188,849 $ 10,444 $ 767,724 Total other revenue 1 (4,609) 6,275 — 1,666 Total operating revenue $ 563,822 $ 195,124 $ 10,444 $ 769,390 _____________ 1 Total other revenue includes revenues from derivatives, PTC deferral revenue and alternative revenue programs that are not considered revenues from contracts with customers. The following tables present disaggregated revenue from contracts with customers and other revenue by major source for the six months ended June 30, 2022 and June 30, 2021: Puget Energy and (Dollars in Thousands) Six Months Ended June 30, 2022 Revenue from contracts with customers: Electric Natural Gas Other 1 Total Retail Residential $ 713,515 $ 451,796 $ — $ 1,165,311 Commercial 483,589 193,254 — 676,843 Industrial 57,784 13,206 — 70,990 Other 9,257 — — 9,257 Wholesale 37,208 — — 37,208 Transmission and transportation 21,855 10,534 — 32,389 Miscellaneous 5,169 362 22,703 28,234 Total revenue from contracts with customers $ 1,328,377 $ 669,152 $ 22,703 $ 2,020,232 Total other revenue 2 22,331 (6,750) — 15,581 Total operating revenue $ 1,350,708 $ 662,402 $ 22,703 $ 2,035,813 _____________ 1 Other includes $0.1 million of Puget LNG revenues recorded at Puget Energy. 2 Total other revenue includes revenues from derivatives and alternative revenue programs that are not considered revenues from contracts with customers. Puget Energy and (Dollars in Thousands) Six Months Ended June 30, 2021 Revenue from contracts with customers: Electric Natural Gas Other Total Retail Residential $ 671,887 $ 397,811 $ — $ 1,069,698 Commercial 436,445 156,283 — 592,728 Industrial 53,376 11,770 — 65,146 Other 10,107 356 — 10,463 Wholesale 50,865 — — 50,865 Transmission and transportation 18,676 10,030 — 28,706 Miscellaneous 32,479 6,700 19,032 58,211 Total revenue from contracts with customers $ 1,273,835 $ 582,950 $ 19,032 $ 1,875,817 Total other revenue 1 48,579 5,080 — 53,659 Total operating revenue $ 1,322,414 $ 588,030 $ 19,032 $ 1,929,476 _____________ 1 Total other revenue includes revenues from derivatives and alternative revenue programs that are not considered revenues from contracts with customers.
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	Based on management’s best estimate of commencement, the Company expects to recognize this revenue over the following time periods: Puget Energy (Dollars in Thousands) 2024 2025 2026 2027 2028 Thereafter Total Remaining Performance Obligations $ 15,359 $ 19,710 $ 19,454 $ 19,454 $ 19,454 $ 102,135 $ 195,566

Accounting for Derivative Ins_2

Accounting for Derivative Instruments and Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 2022
Derivative [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the volumes, fair values and classification of the Company's derivative instruments recorded on the balance sheets: Puget Energy and June 30, 2022 December 31, 2021 (Dollars in Thousands) Volumes (millions) Assets 1 Liabilities 2 Volumes (millions) Assets 1 Liabilities 2 Electric portfolio derivatives * $ 155,126 $ 43,073 * $ 74,829 $ 85,424 Natural gas derivatives (MMBtus) 3 319 123,915 20,518 347 79,578 18,850 Total derivative contracts $ 279,041 $ 63,591 $ 154,407 $ 104,274 Current $ 220,724 $ 53,177 $ 128,210 $ 63,309 Long-term 58,317 10,414 26,197 40,965 Total derivative contracts $ 279,041 $ 63,591 $ 154,407 $ 104,274 _______________ 1 Balance sheet classification: Current and Long-term Unrealized gain on derivative instruments. 2 Balance sheet classification: Current and Long-term Unrealized loss on derivative instruments. 3 All fair value adjustments on derivatives relating to the natural gas business have been deferred in accordance with ASC 980, “Regulated Operations,” due to the purchased gas adjustment (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 231.7 million British Thermal Units (MMBtu) and purchased electricity of 5.6 million at June 30, 2022, and 238.0 million MMBtus and 8.1 million MWhs at December 31, 2021.
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 At June 30, 2022 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 $ 279,041 $ — $ 279,041 $ (30,652) $ — $ 248,389 Liabilities: Energy derivative contracts $ 63,591 $ — $ 63,591 $ (30,652) $ (2,610) $ 30,329 Puget Energy and At December 31, 2021 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 $ 154,407 $ — $ 154,407 $ (40,833) $ — $ 113,574 Liabilities: Energy derivative contracts $ 104,274 $ — $ 104,274 $ (40,833) $ (1,743) $ 61,698 _______________ 1
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	The following table presents the effect and classification of the realized and unrealized gains (losses) of the Company's derivatives recorded on the statements of income: Puget Energy and Three Months Ended Six Months Ended (Dollars in Thousands) Classification 2022 2021 2022 2021 Gas for power derivatives: Unrealized Unrealized gain (loss) on derivative instruments, net $ (16,582) $ 51,241 $ 70,291 $ 52,869 Realized Electric generation fuel 16,039 2,785 43,130 11,098 Power derivatives: Unrealized Unrealized gain (loss) on derivative instruments, net 7,309 10,035 52,357 31,409 Realized Purchased electricity 4,454 6,287 7,045 (7,016) Total gain (loss) recognized in income on derivatives $ 11,220 $ 70,348 $ 172,823 $ 88,360
Schedule of Credit Risk Related Contingent Features	The following table presents the aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position and the amount of additional collateral the Company could be required to post: Puget Energy and (Dollars in Thousands) At June 30, 2022 At December 31, 2021 Fair Value 1 Posted Contingent Fair Value 1 Posted Contingent Contingent Feature Liability Collateral Collateral Liability Collateral Collateral Credit rating 2 $ 16,686 $ — $ 16,686 $ 52,537 $ — $ 52,537 Requested credit for adequate assurance 8,186 — — 9,380 — — Forward value of contract 3 2,610 4,228 N/A 1,743 12,782 N/A Total $ 27,482 $ 4,228 $ 16,686 $ 63,660 $ 12,782 $ 52,537 _______________ 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 (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2022
Fair Value Disclosures [Abstract]
Fair Value Inputs, Liabilities, Quantitative Information	The fair value of the long-term notes was estimated using the discounted cash flow method with the U.S. Treasury yields and the Company's credit spreads as inputs, interpolating to the maturity date of each issue. The carrying values and estimated fair values were as follows: Puget Energy June 30, 2022 December 31, 2021 (Dollars in Thousands) Level Carrying Fair Carrying Fair Liabilities: Long-term debt (fixed-rate), net of discount 1 2 $ 6,622,901 $ 6,556,096 $ 6,170,466 $ 7,769,896 Long-term debt (variable-rate) 2 34,300 34,300 33,300 33,300 Total liabilities $ 6,657,201 $ 6,590,396 $ 6,203,766 $ 7,803,196 Puget Sound Energy June 30, 2022 December 31, 2021 (Dollars in Thousands) Level Carrying Fair Carrying Fair Liabilities: Long-term debt (fixed-rate), net of discount 2 2 $ 4,785,752 $ 4,710,369 $ 4,784,719 $ 6,145,639 Total liabilities $ 4,785,752 $ 4,710,369 $ 4,784,719 $ 6,145,639 _______________ 1 The carrying value includes debt issuances costs of $22.5 million and $22.7 million for June 30, 2022 and December 31, 2021, respectively, which are not included in fair value. 2 The carrying value includes debt issuances costs of $22.1 million and $22.8 million for June 30, 2022 and December 31, 2021, respectively, which are not included in fair value.
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following table presents 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 and Fair Value Fair Value (Dollars in Thousands) Level 2 Level 3 Total Level 2 Level 3 Total Assets: Electric derivative instruments $ 135,724 $ 19,403 $ 155,127 $ 68,011 $ 6,818 $ 74,829 Natural gas derivative instruments 123,158 756 123,914 79,526 52 79,578 Total assets $ 258,882 $ 20,159 $ 279,041 $ 147,537 $ 6,870 $ 154,407 Liabilities: Electric derivative instruments $ 29,585 $ 13,487 $ 43,072 $ 35,854 $ 49,570 $ 85,424 Natural gas derivative instruments 19,046 1,473 20,519 16,678 2,172 18,850 Total liabilities $ 48,631 $ 14,960 $ 63,591 $ 52,532 $ 51,742 $ 104,274
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	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, (Dollars in Thousands) 2022 2021 Level 3 Roll-Forward Net Asset/(Liability) Electric Natural Gas Total Electric Natural Gas Total Balance at beginning of period $ (6,010) $ (1,212) $ (7,222) $ (21,170) $ (1,834) $ (23,004) Changes during period: Realized and unrealized energy derivatives: Included in earnings 1 4,814 — 4,814 14,690 — 14,690 Included in regulatory assets / liabilities — 70 70 — (195) (195) Settlements 7,018 271 7,289 132 167 299 Transferred into Level 3 — — — — — — Transferred out of Level 3 94 154 248 — — — Balance at end of period $ 5,916 $ (717) $ 5,199 $ (6,348) $ (1,862) $ (8,210) Puget Energy and Six Months Ended June 30, (Dollars in Thousands) 2022 2021 Level 3 Roll-Forward Net Asset/(Liability) Electric Natural Gas Total Electric Natural Gas Total Balance at beginning of period $ (42,752) $ (2,120) $ (44,872) $ (23,718) $ (1,135) $ (24,853) Changes during period: Realized and unrealized energy derivatives: Included in earnings 2 43,633 — 43,633 15,510 — 15,510 Included in regulatory assets / liabilities — 485 485 — (1,083) (1,083) Settlements 4,766 595 5,361 1,860 356 2,216 Transferred into Level 3 — — — — — — Transferred out of Level 3 269 323 592 — — — Balance at end of period $ 5,916 $ (717) $ 5,199 $ (6,348) $ (1,862) $ (8,210) _______________ 1 Income Statement locations: Unrealized (gain) loss on derivative instruments, net. Amounts include unrealized gains (losses) on derivatives still held in position as of the reporting date for electric derivatives of $4.6 million and $14.8 million for three months ended June 30, 2022 and 2021, respectively. 2
Fair Value Inputs, Assets and Liabilities, Quantitative Information	The following table presents the forward price ranges for the Company's Level 3 commodity contracts as of June 30, 2022: Puget Energy and Fair Value Range (Dollars in Thousands) Assets 1 Liabilities 1 Valuation Technique Unobservable Input Low High Weighted Average Electric $ 19,403 $ (13,487) Discounted cash flow Power prices (per MWh) $ 33.76 $ 136.57 $ 81.03 Natural gas $ 756 $ (1,473) Discounted cash flow Natural gas prices (per MMBtu) $ 4.48 $ 6.36 $ 5.33 _______________ 1 The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions. The following table presents the forward price ranges for the Company's Level 3 commodity contracts as of December 31, 2021: Puget Energy and Fair Value Range (Dollars in Thousands) Assets 1 Liabilities 1 Valuation Technique Unobservable Input Low High Weighted Average Electric $ 6,818 $ 49,570 Discounted cash flow Power prices (per MWh) $ 21.88 $ 119.38 $ 61.51 Natural gas $ 52 $ 2,172 Discounted cash flow Natural gas prices (per MMBtu) $ 3.65 $ 7.54 $ 5.89 ___________ 1 The valuation techniques, unobservable inputs and ranges are the same for asset and liability positions.

Retirement Benefits (Tables)

Retirement Benefits (Tables)	6 Months Ended
	Jun. 30, 2022
Retirement Benefits [Abstract]
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, 2022 and 2021: Puget Energy Qualified SERP Other Three Months Ended June 30, (Dollars in Thousands) 2022 2021 2022 2021 2022 2021 Components of net periodic benefit cost: Service cost $ 6,378 $ 6,733 $ 139 $ 115 $ 55 $ 41 Interest cost 6,044 5,613 313 293 81 77 Expected return on plan assets (12,730) (12,039) — — (99) (91) Amortization of prior service cost — (476) 72 87 6 2 Amortization of net loss (gain) 1,563 3,072 618 588 (4) (10) Net periodic benefit cost $ 1,255 $ 2,903 $ 1,142 $ 1,083 $ 39 $ 19 Puget Energy Qualified SERP Other Six Months Ended June 30, (Dollars in Thousands) 2022 2021 2022 2021 2022 2021 Components of net periodic benefit cost: Service cost $ 13,175 $ 13,444 $ 279 $ 229 $ 109 $ 82 Interest cost 12,131 11,191 626 586 163 154 Expected return on plan assets (25,507) (24,120) — — (198) (183) Amortization of prior service cost — (952) 145 174 11 3 Amortization of net loss (gain) 3,191 5,901 1,236 1,175 (8) (20) Net periodic benefit cost $ 2,990 $ 5,464 $ 2,286 $ 2,164 $ 77 $ 36 Puget Sound Energy Qualified SERP Other Three Months Ended June 30, (Dollars in Thousands) 2022 2021 2022 2021 2022 2021 Components of net periodic benefit cost: Service cost $ 6,378 $ 6,733 $ 139 $ 115 $ 55 $ 41 Interest cost 6,044 5,613 313 293 81 77 Expected return on plan assets (12,730) (12,040) — — (98) (91) Amortization of prior service cost — (378) 72 87 6 2 Amortization of net loss (gain) 3,734 5,620 662 635 (6) (14) Net periodic benefit cost $ 3,426 $ 5,548 $ 1,186 $ 1,130 $ 38 $ 15 Puget Sound Energy Qualified SERP Other Six Months Ended June 30, (Dollars in Thousands) 2022 2021 2022 2021 2022 2021 Components of net periodic benefit cost: Service cost $ 13,175 $ 13,444 $ 279 $ 229 $ 109 $ 82 Interest cost 12,131 11,191 626 586 163 154 Expected return on plan assets (25,508) (24,121) — — (197) (183) Amortization of prior service cost — (756) 145 174 11 3 Amortization of net loss (gain) 7,540 10,931 1,324 1,271 (11) (28) Net periodic benefit cost $ 7,338 $ 10,689 $ 2,374 $ 2,260 $ 75 $ 28
Schedule of Changes in Projected Benefit Obligations	The following table summarizes the Company’s change in benefit obligation for the periods ended June 30, 2022 and December 31, 2021: Puget Energy and Qualified SERP Other Six Months Ended Year Ended Six Months Ended Year Ended Six Months Ended Year Ended (Dollars in Thousands) June 30, December 31, June 30, December 31, June 30, December 31, Change in benefit obligation: Benefit obligation at beginning of period $ 834,960 $ 849,383 $ 43,155 $ 46,742 $ 11,654 $ 12,114 Amendments — — — — — 205 Service cost 13,175 26,888 279 456 109 155 Interest cost 12,131 22,381 626 1,183 163 302 Actuarial loss (gain) (1,440) (6,826) — 828 — (514) Benefits paid (24,948) (55,831) (990) (6,054) (452) (803) Medicare part D subsidy received — — — — — 195 Administrative Expense — (1,035) — — — — Benefit obligation at end of period $ 833,878 $ 834,960 $ 43,070 $ 43,155 $ 11,474 $ 11,654

Regulation and Rates Public Uti

Regulation and Rates Public Utilities, Regulatory Proceeding (Tables) - Subsidiaries [Member]	6 Months Ended
	Jun. 30, 2022
Purchased Gas Adjustment [Member] | Natural Gas
Regulation and Rates [Line Items]
Schedule of PGA Receivable Payable	The following table presents the PGA mechanism balances and activity at June 30, 2022 and December 31, 2021: (Dollars in Thousands) At June 30, At December 31, PGA receivable balance and activity 2022 2021 PGA receivable beginning balance $ 57,935 $ 87,655 Actual natural gas costs 263,404 364,775 Allowed PGA recovery (267,514) (396,236) Interest 709 1,741 PGA receivable ending balance $ 54,534 $ 57,935
PCA Mechanism [Member] | Electricity
Regulation and Rates [Line Items]
Schedule of Graduated Scale of Rate Adjustment Mechanism	Effective January 1, 2017, the following graduated scale is used in the PCA mechanism: Company’s Share Customers' Share Annual Power Cost Variability Over Under Over Under Over or Under Collected by up to $17 million 100 % 100 % — % — % Over or Under Collected by between $17 million - $40 million 35 50 65 50 Over or Under Collected beyond $40 + million 10 10 90 90

Summary of Consolidation and _3

Summary of Consolidation and Significant Accounting Policy - Narrative (Details) $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($) mi²	Jun. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)
Puget LNG [Member]
Summary of Consolidation Policy
Operating Costs and Expenses	$ 5.4	$ 0.5
Subsidiaries [Member]
Summary of Consolidation Policy
Area of Service Territory (in sqmi) | mi²	6,000
Subsidiaries [Member] | Skookumchuck Wind Energy Project
Summary of Consolidation Policy
Contract Length, PPA	20 years
Variable Interest Entity, Measure of Activity, Expense	$ 7.2	$ 9.1
Variable Interest Entity, Payable	$ 1.3		$ 2.7
Subsidiaries [Member] | Golden Hills Wind Farm
Summary of Consolidation Policy
Contract Length, PPA	20 years
Variable Interest Entity, Measure of Activity, Expense	$ 4.5
Variable Interest Entity, Payable	2.5
Subsidiaries [Member] | Natural Gas, US Regulated [Member] | Tacoma LNG [Member]
Summary of Consolidation Policy
Construction in Progress, Gross			239.6
Public Utilities, Property, Plant and Equipment, Generation or Processing	$ 242
Subsidiaries [Member] | Tacoma LNG [Member]
Summary of Consolidation Policy
Jointly Owned Non-Utility Plant Share	43%
Puget LNG [Member]
Summary of Consolidation Policy
Jointly Owned Non-Utility Plant Share	57%
Puget LNG [Member] | Natural Gas, US Regulated [Member] | Tacoma LNG [Member]
Summary of Consolidation Policy
Jointly Owned Non-Utility Plant, Ownership Amount of Other Assets	$ 246.5
Construction in Progress, Gross			$ 244.7
Variable Interest Entity, Not Primary Beneficiary | Skookumchuck Wind Energy Project
Summary of Consolidation Policy
Equity Method Investments	0
Variable Interest Entity, Not Primary Beneficiary | Golden Hills Wind Farm
Summary of Consolidation Policy
Equity Method Investments	$ 0

Summary of Consolidation and _4

Summary of Consolidation and Significant Accounting Policy - Allowance for Credit Loss (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	$ 34,958	$ 20,080
Provision for Credit Loss	15,727	18,421
Receivables Charged-Off	(8,343)	(5,060)
Total ending allowance balance	42,342	33,441
Bad Debt Deferral, COVID 19	$ 5,100	$ 5,200

Revenue (Details)

Revenue (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Dec. 31, 2020	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		$ 848,473	$ 767,724	$ 2,020,232	$ 1,875,817
Total Other Revenue		(6,097)	1,666	15,581	53,659
Revenues		842,376	769,390	2,035,813	1,929,476
Non-utility expense and other		15,299	9,566	30,718	19,472
Electric		594,331	563,822	1,350,708	1,322,414
Natural gas		236,054	195,124	662,402	588,030
Other		11,991	10,444	22,703	19,032
Residential
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		456,455	391,501	1,165,311	1,069,698
Commercial
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		298,845	259,702	676,843	592,728
Industrial
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		32,832	30,078	70,990	65,146
Other Retail Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		4,496	4,789	9,257	10,463
Wholesale
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		24,061	27,189	37,208	50,865
Transmission and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		15,721	14,319	32,389	28,706
Miscellaneous Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		16,063	40,146	28,234	58,211
Electricity, US Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		594,745	568,431	1,328,377	1,273,835
Total Other Revenue		(414)	(4,609)	22,331	48,579
Electricity, US Regulated [Member] | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		297,255	270,377	713,515	671,887
Electricity, US Regulated [Member] | Commercial
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		226,570	206,806	483,589	436,445
Electricity, US Regulated [Member] | Industrial
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		27,711	25,843	57,784	53,376
Electricity, US Regulated [Member] | Other Retail Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		4,496	4,687	9,257	10,107
Electricity, US Regulated [Member] | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		24,061	27,189	37,208	50,865
Electricity, US Regulated [Member] | Transmission and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		10,633	9,450	21,855	18,676
Electricity, US Regulated [Member] | Miscellaneous Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		4,019	24,079	5,169	32,479
Natural Gas, US Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		241,737	188,849	669,152	582,950
Total Other Revenue		(5,683)	6,275	(6,750)	5,080
Natural Gas, US Regulated [Member] | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		159,200	121,124	451,796	397,811
Natural Gas, US Regulated [Member] | Commercial
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		72,275	52,896	193,254	156,283
Natural Gas, US Regulated [Member] | Industrial
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		5,121	4,235	13,206	11,770
Natural Gas, US Regulated [Member] | Other Retail Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	102	0	356
Natural Gas, US Regulated [Member] | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0	0	0
Natural Gas, US Regulated [Member] | Transmission and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		5,088	4,869	10,534	10,030
Natural Gas, US Regulated [Member] | Miscellaneous Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		53	5,623	362	6,700
Other Revenue From Contracts with Customers [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		11,991	10,444	22,703	19,032
Total Other Revenue		0	0	0	0
Other Revenue From Contracts with Customers [Member] | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0	0	0
Other Revenue From Contracts with Customers [Member] | Commercial
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0	0	0
Other Revenue From Contracts with Customers [Member] | Industrial
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0	0	0
Other Revenue From Contracts with Customers [Member] | Other Retail Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0	0	0
Other Revenue From Contracts with Customers [Member] | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0	0	0
Other Revenue From Contracts with Customers [Member] | Transmission and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0	0	0
Other Revenue From Contracts with Customers [Member] | Miscellaneous Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		11,991	10,444	22,703	19,032
Subsidiaries [Member]
Disaggregation of Revenue [Line Items]
Revenues		842,376	769,390	2,035,778	1,929,476
Non-utility expense and other		11,842	8,952	24,656	18,370
Electric		594,331	563,822	1,350,708	1,322,414
Natural gas		236,054	195,124	662,402	588,030
Other		11,991	$ 10,444	22,668	$ 19,032
Puget LNG [Member]
Disaggregation of Revenue [Line Items]
Revenue, Remaining Performance Obligation, Amount		195,566		195,566
Remaining Contract Term, PLNG	10 years
Puget LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Disaggregation of Revenue [Line Items]
Revenue, Remaining Performance Obligation, Amount		$ 15,359		$ 15,359
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period		1 year		1 year
Puget LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Disaggregation of Revenue [Line Items]
Revenue, Remaining Performance Obligation, Amount		$ 19,710		$ 19,710
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period		1 year		1 year
Puget LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Disaggregation of Revenue [Line Items]
Revenue, Remaining Performance Obligation, Amount		$ 19,454		$ 19,454
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period		1 year		1 year
Puget LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Disaggregation of Revenue [Line Items]
Revenue, Remaining Performance Obligation, Amount		$ 19,454		$ 19,454
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period		1 year		1 year
Puget LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Disaggregation of Revenue [Line Items]
Revenue, Remaining Performance Obligation, Amount		$ 19,454		$ 19,454
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period		1 year		1 year
Puget LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Disaggregation of Revenue [Line Items]
Revenue, Remaining Performance Obligation, Amount		$ 102,135		$ 102,135
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Puget LNG [Member] | Other Revenue From Contracts with Customers [Member] | Miscellaneous Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax				$ 100

Accounting for Derivative Ins_3

Accounting for Derivative Instruments and Hedging Activities Narrative (Details) $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($)
Subsidiaries [Member]
Derivative [Line Items]
Hedging strategy number of years extended	3 years
Natural Gas Portfolio [Member]
Derivative [Line Items]
Posted Collateral	$ 9
External Credit Rating, Investment Grade [Member]
Derivative [Line Items]
Derivative, Credit Risk Exposure, Percentage	99.40%
External Credit Rating, Non Investment Grade [Member]
Derivative [Line Items]
Derivative, Credit Risk Exposure, Percentage	0.60%
Credit Rating [Member] | Natural Gas Portfolio [Member]
Derivative [Line Items]
Posted Collateral	$ 0

Accounting for Derivative Ins_4

Accounting for Derivative Instruments and Hedging Activities Derivative Assets and Liabilities (Details) $ in Thousands, MMBTU in Millions		Jun. 30, 2022 USD ($) MMBTU	Dec. 31, 2021 USD ($) MMBTU
Derivative [Line Items]
Current, Assets		$ 220,724	$ 128,210
Long-term, Assets		58,317	26,197
Current, Liabilities		53,177	63,309
Long-term, Liabilities		10,414	40,965
Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Current, Assets		220,724	128,210
Long-term, Assets		58,317	26,197
Assets	[1]	279,041	154,407
Current, Liabilities		53,177	63,309
Long-term, Liabilities		10,414	40,965
Derivative Liability	[2]	$ 63,591	$ 104,274
Not Designated as Hedging Instrument [Member] | Natural Gas Derivatives [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU		319	347
Not Designated as Hedging Instrument [Member] | Electric Portfolio [Member]
Derivative [Line Items]
Assets		$ 155,126	$ 74,829
Derivative Liability		43,073	85,424
Not Designated as Hedging Instrument [Member] | Natural Gas Portfolio [Member]
Derivative [Line Items]
Assets		123,915	79,578
Derivative Liability		$ 20,518	$ 18,850
Not Designated as Hedging Instrument [Member] | Electric Generation Fuel [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU		231.7	238
Not Designated as Hedging Instrument [Member] | Purchased Electricity [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU		5.6	8.1
[1] _______________ 1 Balance sheet classification: Current and Long-term Unrealized gain on derivative instruments. 2 Balance sheet classification: Current and Long-term Unrealized loss on derivative instruments.

Accounting for Derivative Ins_5

Accounting for Derivative Instruments and Hedging Activities Net Amount of Derivatives Reported in the Statement of Financial Position (Details) - Commodity Contract [Member] - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Assets:
Gross Amount Recognized in the Statement of Financial Position	$ 279,041	$ 154,407
Gross Amounts Offset in the Statement of Financial Position	0	0
Assets	279,041	154,407
Commodity Contracts	(30,652)	(40,833)
Cash Collateral Received	0	0
Net Amount	248,389	113,574
Liabilities:
Gross Amount Recognized in the Statement of Financial Position	63,591	104,274
Gross Amounts Offset in the Statement of Financial Position	0	0
Derivative Liability	63,591	104,274
Commodity Contracts	(30,652)	(40,833)
Cash Collateral Posted	(2,610)	(1,743)
Net Amount	$ 30,329	$ 61,698

Accounting for Derivative Ins_6

Accounting for Derivative Instruments and Hedging Activities Recognized in Statement of Income (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Derivative Instruments, (Loss) Gain [Line Items]
Unrealized (gain) loss on derivative instruments	$ (9,273)	$ 61,276	$ 122,648	$ 84,278
Not Designated as Hedging Instrument [Member]
Derivative Instruments, (Loss) Gain [Line Items]
Unrealized (gain) loss on derivative instruments	11,220	70,348	172,823	88,360
Not Designated as Hedging Instrument [Member] | Electric Generation Fuel [Member] | Unrealized (Gain) Loss on Derivative Instruments, Net [Member]
Derivative Instruments, (Loss) Gain [Line Items]
Unrealized (gain) loss on derivative instruments	(16,582)	51,241	70,291	52,869
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Electric Generation Fuel [Member]
Derivative Instruments, (Loss) Gain [Line Items]
Unrealized (gain) loss on derivative instruments	16,039	2,785	43,130	11,098
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Purchased Electricity [Member]
Derivative Instruments, (Loss) Gain [Line Items]
Unrealized (gain) loss on derivative instruments	4,454	6,287	7,045	(7,016)
Not Designated as Hedging Instrument [Member] | Electricity, US Regulated [Member] | Unrealized (Gain) Loss on Derivative Instruments, Net [Member]
Derivative Instruments, (Loss) Gain [Line Items]
Unrealized (gain) loss on derivative instruments	$ 7,309	$ 10,035	$ 52,357	$ 31,409

Accounting for Derivative Ins_7

Accounting for Derivative Instruments and Hedging Activities Contractual Contingent Liability (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Electric Portfolio [Member]
Derivative [Line Items]
Fair Value Liability	$ 27,482	$ 63,660
Posted Collateral	4,228	12,782
Additional Collateral, Aggregate Fair Value	16,686	52,537
Natural Gas Portfolio [Member]
Derivative [Line Items]
Posted Collateral	9,000
Electricity, US Regulated [Member]
Derivative [Line Items]
Posted Collateral	4,200
Credit Rating [Member] | Electric Portfolio [Member]
Derivative [Line Items]
Fair Value Liability	16,686	52,537
Posted Collateral	0	0
Additional Collateral, Aggregate Fair Value	16,686	52,537
Credit Rating [Member] | Natural Gas Portfolio [Member]
Derivative [Line Items]
Posted Collateral	0
Requested Credit for Adequate Assurance [Member] | Electric Portfolio [Member]
Derivative [Line Items]
Fair Value Liability	8,186	9,380
Posted Collateral	0	0
Additional Collateral, Aggregate Fair Value	0	0
Forward Value of Contract [Member] | Electric Portfolio [Member]
Derivative [Line Items]
Fair Value Liability	2,610	1,743
Posted Collateral	$ 4,228	$ 12,782

Fair Value Measurements Debt at

Fair Value Measurements Debt at at Carrying and Fair Value (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Liabilities:
Total long-term debt	$ 6,657,201	$ 6,203,766
Carrying Value [Member] | Level 2 [Member]
Liabilities:
Notes Receivable, Fair Value Disclosure	54,500	53,200
Subsidiaries [Member]
Liabilities:
Total long-term debt	4,785,752	4,784,719
Discounted cash flow [Member] | Fair Value [Member]
Liabilities:
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	6,590,396	7,803,196
Discounted cash flow [Member] | Fair Value [Member] | Level 2 [Member]
Liabilities:
Long-term debt (fixed-rate), net of discount	6,556,096	7,769,896
Long-term debt (variable-rate)	34,300	33,300
Discounted cash flow [Member] | Carrying Value [Member]
Liabilities:
Long-term Debt, Excluding Current Maturities, Fair Value Disclosure	6,657,201	6,203,766
Discounted cash flow [Member] | Carrying Value [Member] | Level 2 [Member]
Liabilities:
Long-term debt (fixed-rate), net of discount	6,622,901	6,170,466
Long-term debt (variable-rate)	34,300	33,300
Debt issuance costs	22,500	22,700
Discounted cash flow [Member] | Subsidiaries [Member] | Fair Value [Member]
Liabilities:
Total long-term debt	4,710,369	6,145,639
Discounted cash flow [Member] | Subsidiaries [Member] | Fair Value [Member] | Level 2 [Member]
Liabilities:
Long-term debt (fixed-rate), net of discount	4,710,369	6,145,639
Discounted cash flow [Member] | Subsidiaries [Member] | Carrying Value [Member]
Liabilities:
Total long-term debt	4,785,752	4,784,719
Discounted cash flow [Member] | Subsidiaries [Member] | Carrying Value [Member] | Level 2 [Member]
Liabilities:
Long-term debt (fixed-rate), net of discount	4,785,752	4,784,719
Debt issuance costs	$ 22,100	$ 22,800

Fair Value Measurements Assets

Fair Value Measurements Assets and Liabilities (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Mar. 31, 2022	Dec. 31, 2021	Mar. 31, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	$ 5,199	$ (8,210)	$ 5,199	$ (8,210)	$ (7,222)	$ (44,872)	$ (23,004)	$ (24,853)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	4,814	14,690	43,633	15,510
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Regulatory Assets (Liabilities)	70	(195)	485	(1,083)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	7,289	299	5,361	2,216
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3	0	0	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers out of Level 3	248	0	592	0
Electric Portfolio [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	5,916	(6,348)	5,916	(6,348)	(6,010)	(42,752)	(21,170)	(23,718)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	4,814	14,690	43,633	15,510
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Regulatory Assets (Liabilities)	0	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	7,018	132	4,766	1,860
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3	0	0	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers out of Level 3	94	0	269	0
Gain (loss) on derivatives	4,600	14,800	40,800	15,600
Natural Gas Portfolio [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	(717)	(1,862)	(717)	(1,862)	$ (1,212)	(2,120)	$ (1,834)	$ (1,135)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	0	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Regulatory Assets (Liabilities)	70	(195)	485	(1,083)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	271	167	595	356
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3	0	0	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers out of Level 3	154	$ 0	323	$ 0
Fair Value, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	279,041		279,041			154,407
Derivative Liability	63,591		63,591			104,274
Fair Value, Recurring [Member] | Electric Portfolio [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	155,127		155,127			74,829
Derivative Liability	43,072		43,072			85,424
Fair Value, Recurring [Member] | Natural Gas Portfolio [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	123,914		123,914			79,578
Derivative Liability	20,519		20,519			18,850
Fair Value, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	258,882		258,882			147,537
Derivative Liability	48,631		48,631			52,532
Fair Value, Recurring [Member] | Level 2 [Member] | Electric Portfolio [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	135,724		135,724			68,011
Derivative Liability	29,585		29,585			35,854
Fair Value, Recurring [Member] | Level 2 [Member] | Natural Gas Portfolio [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	123,158		123,158			79,526
Derivative Liability	19,046		19,046			16,678
Fair Value, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	20,159		20,159			6,870
Derivative Liability	14,960		14,960			51,742
Fair Value, Recurring [Member] | Level 3 [Member] | Electric Portfolio [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	19,403		19,403			6,818
Derivative Liability	13,487		13,487			49,570
Fair Value, Recurring [Member] | Level 3 [Member] | Natural Gas Portfolio [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	756		756			52
Derivative Liability	$ 1,473		$ 1,473			$ 2,172

Fair Value Measurements Valuati

Fair Value Measurements Valuation Techniques for Measurement with Unobservable Inputs (Details)	6 Months Ended	12 Months Ended
	Jun. 30, 2022 USD ($) $ / MWh $ / MMBTU	Dec. 31, 2021 USD ($) $ / MWh $ / MMBTU
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value measurement, sensitivity analysis, hypothetical increase or decrease of market prices, result on fair value	0.10%
Fair Value Measurements, Sensitivity Analysis, Hypothetical Increase or Decrease of Market Prices, Result on Fair Value	$ 20,300,000	$ 17,900,000
Impairment of Intangible Assets, Finite-lived	0
Fair Value, Recurring [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets	279,041,000	154,407,000
Derivative Liability	63,591,000	104,274,000
Fair Value, Recurring [Member] | Level 3 [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets	20,159,000	6,870,000
Derivative Liability	$ 14,960,000	$ 51,742,000
Electric Portfolio [Member] | Discounted cash flow [Member] | Low [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Price (per MWh) | $ / MWh	33.76	21.88
Electric Portfolio [Member] | Discounted cash flow [Member] | High [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Price (per MWh) | $ / MWh	136.57	119.38
Electric Portfolio [Member] | Discounted cash flow [Member] | Weighted Average [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Price (per MWh) | $ / MWh	81.03	61.51
Electric Portfolio [Member] | Fair Value, Recurring [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets	$ 155,127,000	$ 74,829,000
Derivative Liability	43,072,000	85,424,000
Electric Portfolio [Member] | Fair Value, Recurring [Member] | Level 3 [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets	19,403,000	6,818,000
Derivative Liability	13,487,000	49,570,000
Electric Portfolio [Member] | Fair Value, Recurring [Member] | Parent Company [Member] | Level 3 [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets	19,403,000	6,818,000
Derivative Liability	$ (13,487,000)	$ 49,570,000
Natural Gas Portfolio [Member] | Discounted cash flow [Member] | Low [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Price Per Millions of BTU | $ / MMBTU	4.48	3.65
Natural Gas Portfolio [Member] | Discounted cash flow [Member] | High [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Price Per Millions of BTU | $ / MMBTU	6.36	7.54
Natural Gas Portfolio [Member] | Discounted cash flow [Member] | Weighted Average [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Price Per Millions of BTU | $ / MMBTU	5.33	5.89
Natural Gas Portfolio [Member] | Fair Value, Recurring [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets	$ 123,914,000	$ 79,578,000
Derivative Liability	20,519,000	18,850,000
Natural Gas Portfolio [Member] | Fair Value, Recurring [Member] | Level 3 [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets	756,000	52,000
Derivative Liability	1,473,000	2,172,000
Natural Gas Portfolio [Member] | Fair Value, Recurring [Member] | Parent Company [Member] | Level 3 [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets	756,000	52,000
Derivative Liability	$ (1,473,000)	$ 2,172,000

Retirement Benefits Net Periodi

Retirement Benefits Net Periodic Benefit Cost (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Qualified Pension Benefits [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Defined Benefit Plan, Service Cost			$ 13,175	$ 13,444	$ 26,888
Defined Benefit Plan, Interest Cost			12,131	11,191	22,381
Defined Benefit Plan, Expected Return (Loss) on Plan Assets			(25,507)	(24,120)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)			0	(952)
Defined Benefit Plan, Amortization of Gain (Loss)			3,191	5,901
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total			2,990	5,464
Qualified Pension Benefits [Member] | Parent Company [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Defined Benefit Plan, Service Cost	$ 6,378	$ 6,733
Defined Benefit Plan, Interest Cost	6,044	5,613
Defined Benefit Plan, Expected Return (Loss) on Plan Assets	(12,730)	(12,039)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	0	(476)
Defined Benefit Plan, Amortization of Gain (Loss)	1,563	3,072
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total	1,255	2,903
Qualified Pension Benefits [Member] | Subsidiaries [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Defined Benefit Plan, Service Cost	6,378	6,733	13,175	13,444
Defined Benefit Plan, Interest Cost	6,044	5,613	12,131	11,191
Defined Benefit Plan, Expected Return (Loss) on Plan Assets	(12,730)	(12,040)	(25,508)	(24,121)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	0	(378)	0	(756)
Defined Benefit Plan, Amortization of Gain (Loss)	3,734	5,620	7,540	10,931
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total	3,426	5,548	7,338	10,689
Supplemental Employee Retirement Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Defined Benefit Plan, Service Cost			279	229	456
Defined Benefit Plan, Interest Cost			626	586	1,183
Defined Benefit Plan, Expected Return (Loss) on Plan Assets			0	0
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)			145	174
Defined Benefit Plan, Amortization of Gain (Loss)			1,236	1,175
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total			2,286	2,164
Supplemental Employee Retirement Plan [Member] | Parent Company [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Defined Benefit Plan, Service Cost	139	115
Defined Benefit Plan, Interest Cost	313	293
Defined Benefit Plan, Expected Return (Loss) on Plan Assets	0	0
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	72	87
Defined Benefit Plan, Amortization of Gain (Loss)	618	588
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total	1,142	1,083
Supplemental Employee Retirement Plan [Member] | Subsidiaries [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Defined Benefit Plan, Service Cost	139	115	279	229
Defined Benefit Plan, Interest Cost	313	293	626	586
Defined Benefit Plan, Expected Return (Loss) on Plan Assets	0	0	0	0
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	72	87	145	174
Defined Benefit Plan, Amortization of Gain (Loss)	662	635	1,324	1,271
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total	1,186	1,130	2,374	2,260
Other Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Defined Benefit Plan, Service Cost			109	82	155
Defined Benefit Plan, Interest Cost			163	154	$ 302
Defined Benefit Plan, Expected Return (Loss) on Plan Assets			(198)	(183)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)			11	3
Defined Benefit Plan, Amortization of Gain (Loss)			(8)	(20)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total			77	36
Other Benefit [Member] | Parent Company [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Defined Benefit Plan, Service Cost	55	41
Defined Benefit Plan, Interest Cost	81	77
Defined Benefit Plan, Expected Return (Loss) on Plan Assets	(99)	(91)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	6	2
Defined Benefit Plan, Amortization of Gain (Loss)	(4)	(10)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total	39	19
Other Benefit [Member] | Subsidiaries [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Defined Benefit Plan, Service Cost	55	41	109	82
Defined Benefit Plan, Interest Cost	81	77	163	154
Defined Benefit Plan, Expected Return (Loss) on Plan Assets	(98)	(91)	(197)	(183)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	6	2	11	3
Defined Benefit Plan, Amortization of Gain (Loss)	(6)	(14)	(11)	(28)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total	$ 38	$ 15	$ 75	$ 28

Retirement Benefits Change in N

Retirement Benefits Change in Net Benefit Obligation (Details) - USD ($) $ in Thousands	6 Months Ended		12 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Qualified Pension Benefits [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Beginning Balance	$ 834,960	$ 849,383	$ 849,383
Defined Benefit Plan, Service Cost	13,175	13,444	26,888
Defined Benefit Plan, Interest Cost	12,131	11,191	22,381
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	(1,440)		(6,826)
Defined Benefit Plan, Benefit Obligation, Benefits Paid	(24,948)		(55,831)
Defined Benefit Plan, Benefit Obligation, Prescription Drug Subsidy Receipt	0		0
Administrative Expense	0		(1,035)
Defined Benefit Plan, Benefit Obligation, Ending Balance	833,878		834,960
Supplemental Employee Retirement Plan [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Beginning Balance	43,155	46,742	46,742
Defined Benefit Plan, Service Cost	279	229	456
Defined Benefit Plan, Interest Cost	626	586	1,183
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	0		828
Defined Benefit Plan, Benefit Obligation, Benefits Paid	(990)		(6,054)
Defined Benefit Plan, Benefit Obligation, Prescription Drug Subsidy Receipt	0		0
Administrative Expense	0		0
Defined Benefit Plan, Benefit Obligation, Ending Balance	43,070		43,155
Other Benefit [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Beginning Balance	11,654	12,114	12,114
Defined Benefit Plan, Benefit Obligation, Increase (Decrease) for Plan Amendment	0		(205)
Defined Benefit Plan, Service Cost	109	82	155
Defined Benefit Plan, Interest Cost	163	$ 154	302
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	0		(514)
Defined Benefit Plan, Benefit Obligation, Benefits Paid	(452)		(803)
Defined Benefit Plan, Benefit Obligation, Prescription Drug Subsidy Receipt	0		195
Administrative Expense	0		0
Defined Benefit Plan, Benefit Obligation, Ending Balance	11,474		11,654
Qualified Plan [Member] | Qualified Pension Benefits [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Increase (Decrease) for Plan Amendment	0		0
Nonqualified Plan [Member] | Supplemental Employee Retirement Plan [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Increase (Decrease) for Plan Amendment	$ 0		$ 0

Retirement Benefits Activity (D

Retirement Benefits Activity (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2022
Subsidiaries [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Interest Credit	4%
UA represented [Member] | employer contribution [Member] | Subsidiaries [Member] | Collective Bargaining Arrangement [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay	4%
IBEW represented | employer contribution [Member] | Subsidiaries [Member] | Collective Bargaining Arrangement [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	4%
Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employer contributions	$ 1	$ 1
Forecast [Member] | Qualified Pension Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Aggregate expected contributions			$ 18
Forecast [Member] | Supplemental Employee Retirement Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Aggregate expected contributions			2.8
Forecast [Member] | Other Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Aggregate expected contributions			$ 0.3

Regulation and Rates (Details)

Regulation and Rates (Details) - USD ($)															3 Months Ended		6 Months Ended			12 Months Ended
	Nov. 15, 2021	Nov. 01, 2021	Oct. 01, 2021	Sep. 28, 2021	Jul. 01, 2021	Apr. 12, 2021	Mar. 02, 2021	Feb. 02, 2021	Dec. 09, 2020	Oct. 15, 2020	Oct. 01, 2020	Jul. 08, 2020	Jun. 20, 2019	Apr. 10, 2019	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Sep. 30, 2020	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2021	Dec. 31, 2020	Apr. 13, 2020	Jan. 01, 2018
Regulatory Assets [Line Items]
Income tax (benefit) expense															$ 4,156,000	$ 12,331,000	$ 23,967,000	$ 14,484,000
Depreciation & amortization															165,676,000	165,930,000	330,252,000	374,361,000
Other Regulatory Assets															797,867,000		797,867,000						$ 815,058,000
Revenues															842,376,000	769,390,000	2,035,813,000	1,929,476,000
purchase gas adjustment, long-term															54,534,000		54,534,000						57,935,000
Subsidiaries [Member]
Regulatory Assets [Line Items]
Income tax (benefit) expense															3,708,000	14,425,000	38,564,000	31,051,000
Annual Power Cost Variability, Interest																	600,000	700,000
Depreciation & amortization															164,009,000	165,803,000	327,713,000	374,165,000
Liabilities, Other than Long-term Debt, Noncurrent	$ 34,500,000																								$ 11,000,000
Customer Bill Assistance	2,500					$ 2,500													$ 1,000
Other Regulatory Assets															797,867,000		797,867,000						815,058,000
Revenues															842,376,000	$ 769,390,000	2,035,778,000	1,929,476,000
purchase gas adjustment, long-term															$ 54,534,000		54,534,000						57,935,000	$ 87,655,000
Subsidiaries [Member] | Under-collection [Member]
Regulatory Assets [Line Items]
Annual Power Cost Variability, Amount																	26,600,000	30,500,000					68,000,000	76,100,000
Subsidiaries [Member] | Under-collection [Member] | Companys share [Member]
Regulatory Assets [Line Items]
Annual Power Cost Variability, Amount																							31,300,000	32,100,000
Subsidiaries [Member] | Under-collection [Member] | Customer's share [Member]
Regulatory Assets [Line Items]
Annual Power Cost Variability, Amount																	4,800,000	6,700,000					36,700,000	44,000,000
Subsidiaries [Member] | Under-collection [Member] | Customer's share plus interest
Regulatory Assets [Line Items]
Annual Power Cost Variability, Amount																							38,400,000	46,000,000
Subsidiaries [Member] | Maximum Power | Customer's share plus interest
Regulatory Assets [Line Items]
Annual Power Cost Variability, Amount																							20,000,000	$ 20,000,000
Subsidiaries [Member] | Electricity, US Regulated [Member]
Regulatory Assets [Line Items]
Storm Damage Costs Incurred During Period																	6,700,000	23,600,000
Public Utilities, Rate Case, Deferred Storm Costs Threshold																										$ 10,000,000
Public Utilities, Rate Case, Deferred Storm Qualifying Costs																										$ 500,000
Subsidiaries [Member] | Electricity
Regulatory Assets [Line Items]
Liabilities, Other than Long-term Debt, Noncurrent	23,700,000					20,000,000
Subsidiaries [Member] | Natural Gas
Regulatory Assets [Line Items]
Liabilities, Other than Long-term Debt, Noncurrent	$ 10,800,000					$ 7,700,000
General Rate Case [Member] | Subsidiaries [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount			$ 18,900,000
Regulatory assets and additional revenues																							24,500,000
General Rate Case [Member] | Subsidiaries [Member] | Electricity, US Regulated [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Percentage													6.90%
Public Utilities, Approved Rate Increase (Decrease), Amount			$ 15,800,000	$ 48,300,000						$ 900,000
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount				$ 77,100,000
Public Utilities, Requested Rate Increase (Decrease), Amended, Percentage				3.70%
Public Utilities, Approved Rate Increase (Decrease), Percentage			0.70%	2.30%						0.05%
Public Utilities, Approved Debt Capital Structure, Percentage												7.39%
Public Utilities, Interim Rate Increase (Decrease), Amount				$ 59,600,000								$ 29,500,000
Public Utilities, Interim Rate Increase (Decrease), Percentage												1.60%
PublicUtilitiesIncremenalRateIncreaseDecreaseAmount				17,500,000
General Rate Case [Member] | Subsidiaries [Member] | Natural Gas, US Regulated [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Percentage													7.90%
Public Utilities, Approved Rate Increase (Decrease), Amount			$ 3,100,000	4,900,000							$ 1,300,000
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount				$ 45,300,000
Public Utilities, Requested Rate Increase (Decrease), Amended, Percentage				5.90%
Public Utilities, Approved Rate Increase (Decrease), Percentage			0.30%	0.60%							0.15%
Public Utilities, Interim Rate Increase (Decrease), Amount				$ 42,900,000								$ 36,500,000
Public Utilities, Interim Rate Increase (Decrease), Percentage												4%
PublicUtilitiesIncremenalRateIncreaseDecreaseAmount				$ 2,400,000
General Rate Case [Member] | Maximum [Member] | Subsidiaries [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Debt Capital Structure, Net of Tax, Percentage												6.80%
Public Utilities, Approved Equity Capital Structure, Percentage												48.50%
Public Utilities, Approved Return on Equity, Percentage												9.40%
Decoupling Mechanism [Member]
Regulatory Assets [Line Items]
Deferred Revenue, Revenue Recognized																		0
Decoupling Mechanism [Member] | Subsidiaries [Member] | Electricity, US Regulated [Member]
Regulatory Assets [Line Items]
Contract with Customer, Liability, Revenue Recognized																	0	800,000
Decoupling Mechanism [Member] | Subsidiaries [Member] | Natural Gas, US Regulated [Member]
Regulatory Assets [Line Items]
Contract with Customer, Liability, Revenue Recognized																	0
Purchased Gas Adjustment [Member] | Subsidiaries [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 59,100,000
Purchased natural gas costs																	263,404,000						364,775,000
Purchased natural gas costs, recoverable																	(267,514,000)						(396,236,000)
Purchased natural gas adjustment, interest																	709,000						1,741,000
Out of Cycle PGA		69,400,000
Get to Zero Deferral Filing [Member] | Subsidiaries [Member]
Regulatory Assets [Line Items]
Regulated Utility, Allowed Rate of Return on Net Regulatory Assets and Liabilities														6.89%
Depreciation & amortization																	9,200,000						$ 6,600,000
Public Utilities, Property, Plant and Equipment, Equipment, Useful Life														10 years
Power Cost Only Rate Case | Subsidiaries [Member] | Electricity, US Regulated [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Percentage							3.10%	4.10%	3.70%
Public Utilities, Requested Rate Increase (Decrease), Amount							$ 65,300,000	$ 88,000,000	$ 78,500,000
Public Utilities, Approved Rate Increase (Decrease), Amount					$ 70,900,000
Public Utilities, Approved Rate Increase (Decrease), Percentage					3.30%
Purchased Gas Adjustment, Schedule 101 | Subsidiaries [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount		80,600,000
purchased gas adjustment, Schedule 106 106B | Subsidiaries [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount		$ (21,500,000)
storm that occurred in 2020 [Member] | Subsidiaries [Member] | Electricity, US Regulated [Member]
Regulatory Assets [Line Items]
Storm Damage Costs Deferred During Period																		200,000
Storm that occurred in 2021 | Subsidiaries [Member] | Electricity, US Regulated [Member]
Regulatory Assets [Line Items]
Storm Damage Costs Deferred During Period																	$ 100,000	$ 13,600,000
Forecast [Member] | General Rate Case [Member] | Subsidiaries [Member]
Regulatory Assets [Line Items]
Regulated Utility, Allowed Rate of Return on Net Regulatory Assets and Liabilities																				7.49%	7.44%	7.39%
Public Utilities, Requested Return on Equity, Percentage																				9.90%	9.90%	9.90%
Forecast [Member] | General Rate Case [Member] | Subsidiaries [Member] | Electricity, US Regulated [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Percentage																				1.20%	2.50%	13.60%
Forecast [Member] | General Rate Case [Member] | Subsidiaries [Member] | Natural Gas, US Regulated [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Percentage																				1.80%	2.30%	13%

Schedule of Power Cost Adjustme

Schedule of Power Cost Adjustment Mechanism (Details) - Subsidiaries [Member] $ in Millions	6 Months Ended		12 Months Ended
	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability, Interest	$ 0.6	$ 0.7
Under-collection [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability, Amount	26.6	30.5	$ 68	$ 76.1
Under-collection [Member] | Companys share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability, Amount			31.3	32.1
Under-collection [Member] | Customer's share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability, Amount	$ 4.8	$ 6.7	36.7	44
Under-collection [Member] | Customer's share plus interest
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability, Amount			38.4	46
Maximum Power | Customer's share plus interest
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability, Amount			$ 20	$ 20
Range 1 [Member] | Over-collection [Member] | Companys share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	1
Range 1 [Member] | Over-collection [Member] | Customer's share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	0
Range 1 [Member] | Under-collection [Member] | Companys share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	1
Range 1 [Member] | Under-collection [Member] | Customer's share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	0
Range 2 [Member] | Over-collection [Member] | Companys share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	0.35
Range 2 [Member] | Over-collection [Member] | Customer's share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	0.65
Range 2 [Member] | Under-collection [Member] | Companys share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	0.50
Range 2 [Member] | Under-collection [Member] | Customer's share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	0.50
Range 3 [Member] | Over-collection [Member] | Companys share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	0.10
Range 3 [Member] | Over-collection [Member] | Customer's share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	0.90
Range 3 [Member] | Under-collection [Member] | Companys share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	0.10
Range 3 [Member] | Under-collection [Member] | Customer's share [Member]
Regulatory Assets and Liabiliaties [Line Items]
Annual Power Cost Variability	0.90

Commitments and Contingencies (

Commitments and Contingencies (Details)	Jun. 30, 2022
Colstrip Units 1 and 2 [Member]
Loss Contingencies [Line Items]
Ownership interest (percent)	50%
Colstrip Units 3 and 4 [Member]
Loss Contingencies [Line Items]
Ownership interest (percent)	25%

Leases - Supplemental balance s

Leases - Supplemental balance sheet information related to leases (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Lessee, Operating Lease, Description [Abstract]
Operating Lease, Right-of-Use Asset	$ 179,909	$ 184,957
Operating Lease, Liability, Current	21,135	20,398
Operating Lease, Liability, Noncurrent	$ 166,238	$ 172,510

Other - Narrative (Details)

Other - Narrative (Details) - USD ($)		3 Months Ended	6 Months Ended
	Apr. 28, 2022	Jun. 30, 2022	Jun. 30, 2022	Jun. 30, 2021	Mar. 17, 2022	Dec. 31, 2021	Sep. 15, 2021	Jun. 14, 2021
Debt Instrument [Line Items]
Long-term Debt, Current Maturities		$ 0	$ 0			$ 450,000,000
Repayments of Long-term Debt			450,000,000	$ 66,000
Line of Credit Facility, Maximum Borrowing Capacity		800,000,000	800,000,000
Line of Credit Facility, Maximum Amount Outstanding During Period			43,300,000
Short-term Debt		64,000,000	64,000,000			140,000,000
Line of Credit, Current		9,000,000	9,000,000
Long-term Line of Credit, Noncurrent		34,300,000	34,300,000
Subsidiaries [Member]
Debt Instrument [Line Items]
Repayments of Long-term Debt			0	$ 66,000
Line of Credit Facility, Maximum Borrowing Capacity		800,000,000	800,000,000
Commercial Paper		55,000,000	55,000,000
Short-term Debt		55,000,000	55,000,000			$ 140,000,000
2.379% Senior Secured Note Due 2028 [Member] | Senior Secured Note
Debt Instrument [Line Items]
Long-term Debt, Gross								$ 500,000,000
Debt Instrument, Interest Rate, Stated Percentage								2.379%
6.000% Senior Secured Note Due 2021 | Senior Secured Note
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage								6%
Long-term Debt, Current Maturities								$ 500,000,000
$210M Term Loan Due 2022
Debt Instrument [Line Items]
Repayments of Long-term Debt		$ 210,000,000
Working Capital Needs [Member] | Subsidiaries [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Amount Outstanding During Period			0
2.893% Senior Secured Note Due 2051 | Senior Secured Note | Subsidiaries [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross							$ 450,000,000
Debt Instrument, Interest Rate, Stated Percentage							2.893%
4.224% Senior Secured Note Due 2032 | Senior Secured Note
Debt Instrument [Line Items]
Long-term Debt, Gross					$ 450,000,000
Debt Instrument, Interest Rate, Stated Percentage					4.224%
5.625% Senior Secured Note Due 2022 | Senior Secured Note
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.625%
Long-term debt, Principal	$ 450,000,000
Debt Instrument, Increase, Accrued Interest			$ 7,200,000
Extinguishment of Debt, Amount	$ 457,200,000