UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q


[X]			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2025


[ ]			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the Transition period from ________ to ________


Commission File Number			Exact name of registrant as specified in its charter, state of incorporation, address of principal executive offices, telephone number			I.R.S. Employer Identification Number


1-16305			PUGET ENERGY, INC. A Washington Corporation 355 110th Ave NE Bellevue, Washington 98004 (425) 454-6363			91-1969407


1-4393			PUGET SOUND ENERGY, INC. A Washington Corporation 355 110th Ave NE Bellevue, Washington 98004 (425) 454-6363			91-0374630

Securities Registered pursuant to Section 12(b) of the Securities Exchange Act of 1934


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
N/A	N/A	N/A

Indicate by check mark whether the registrants: (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.

Puget Energy, Inc.

Yes

/X/

/ /

Puget Sound Energy, Inc.

Yes

/X/

/ /

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Puget Energy, Inc.

Yes

/X/

/ /

Puget Sound Energy, Inc.

Yes

/X/

/ /

Indicate by check mark whether the registrants are a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer," "accelerated filer," "smaller reporting company,” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Puget Energy, Inc.

Large accelerated filer

/ /

Accelerated filer

/ /

Non-accelerated Filer

/X/

Smaller reporting company

/ /

Emerging growth company

/ /

Puget Sound Energy, Inc.

Large accelerated filer

/ /

Accelerated filer

/ /

Non-accelerated Filer

/X/

Smaller reporting company

/ /

Emerging growth company

/ /

DEFINITIONS


ASU			Accounting Standards Update
ARO			Asset Retirement Obligation
ASC			Accounting Standards Codification
CCA			Climate Commitment Act
CEIP			Clean Energy Implementation Plan
CETA			Clean Energy Transformation Act
CWIP			Construction Work in Progress
EBITDA			Earnings Before Interest, Tax, Depreciation and Amortization
FASB			Financial Accounting Standards Board
GAAP			U.S. Generally Accepted Accounting Principles
GHG			Greenhouse gases
GRC			General Rate Case
IBEW			International Brotherhood of Electrical Workers
IOU			Investor-Owned Utility
ISDA			International Swaps and Derivatives Association
LNG			Liquefied Natural Gas
MMBtu			One Million British Thermal Units
MWh			Megawatt Hour (one MWh equals one thousand kWh)
MYRP			Multi-year Rate Plan
NAESB			North American Energy Standards Board
NPNS			Normal Purchase Normal Sale
O&M			Operations and Maintenance
PCA			Power Cost Adjustment
PGA			Purchased Gas Adjustment
PTCs			Production Tax Credits
PSE			Puget Sound Energy, Inc.
Puget Energy			Puget Energy, Inc.
Puget Holdings			Puget Holdings LLC
Puget LNG			Puget LNG, LLC
SERP			Supplemental Executive Retirement Plan
UA			The United Association of Journeymen and Apprentices of the Plumbing and Pipefitting Industry of the United States and Canada
Washington Commission			Washington Utilities and Transportation Commission
WDOE			Washington Department of Ecology
WSPP			WSPP, Inc.

FILING FORMAT

This combined Quarterly Report on Form 10-Q is separately filed by Puget Energy, Inc. (Puget Energy) and Puget Sound Energy, Inc. (PSE). Information in this filing relating to PSE is filed by PSE on its own behalf. PSE makes no representation as to information relating to Puget Energy (except as it may relate to PSE) or any other affiliate or subsidiary of Puget Energy. Any references in this report to “the Company” are to Puget Energy and PSE collectively.

FORWARD-LOOKING STATEMENTS

Puget Energy and PSE include the following cautionary statements in this Form 10-Q to make applicable and to take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 for any forward-looking statements made by or on behalf of Puget Energy or PSE. This report includes forward-looking statements, which are statements of expectations, beliefs, plans, objectives and assumptions of future events or performance. Words or phrases such as “anticipates,” “believes,” “continues,” “could,” “estimates,” “expects,” “future,” “intends,” “may,” “might,” “plans,” “potential,” “predicts,” “projects,” “should,” “will likely result,” “will continue” or similar expressions are intended to identify certain of these forward-looking statements and may be included in discussion of, among other things, our anticipated operating or financial performance, business plans and prospects, planned capital expenditures and other future expectations. In particular, these include statements relating to future actions, business plans and prospects, future performance expenses, the outcome of contingencies, such as legal proceedings, government regulation and financial results.

Forward-looking statements reflect current expectations and involve risks and uncertainties that could cause actual results or outcomes to differ materially from those expressed. There can be no assurance that Puget Energy’s and PSE’s expectations, beliefs or projections will be achieved or accomplished.

In addition to other factors and matters discussed elsewhere in this report, some important risks that could cause actual results or outcomes for Puget Energy and PSE to differ materially from past results and those discussed in the forward-looking statements include:


●			Governmental policies and regulatory actions, including those of the Federal Energy Regulatory Commission and the Washington Commission, that may affect our ability to recover costs and earn a reasonable return, including but not limited to disallowance or delays in the recovery of capital investments and operating costs and discretion over allowed return on investment;
●			Changes in, adoption of and compliance with laws and regulations, related to executive orders, federal grant programs, incentives and funding policies, tariffs and trade restrictions and budget and efficiency measures, including any actual or potential reduction in the federal workforce, decisions and policies concerning the environment, climate change, greenhouse gas or other emissions or by-products of electric generation (including coal ash or other substances) or natural gas distribution and sales, natural resources, and fish and wildlife (including the Endangered Species Act and Migratory Bird Treaty Act) as well as the risk of litigation arising from such matters, whether involving public or private claimants or regulatory investigative or enforcement measures;
●			Changes in tax law, related regulations or differing interpretation, or enforcement of applicable law by the Internal Revenue Service (IRS) or other taxing jurisdiction; and PSE's ability to recover costs in a timely manner arising from such changes;
●			Inability to realize deferred tax assets and use PTCs due to insufficient future taxable income;
●			Accidents or natural disasters, such as hurricanes, windstorms, earthquakes, floods, landslides, fires and wildfires (either affecting or caused by PSE's facilities or infrastructure), extreme weather conditions and other acts of God, terrorism, asset-based or cyber-based attacks, pandemics or similar significant events, changes in legislation, regulation and government policies including federal grant programs, trade restrictions and tariffs, and government staff reductions can delay projects, interrupt service and lead to lost revenue, cause temporary supply disruptions and/or price spikes in the cost of fuel and raw materials, impose extraordinary costs, and subject the Company to liability;
●			Commodity price risks associated with procuring natural gas and power in wholesale markets from creditworthy counterparties;
●			Wholesale market disruption, which may result in a deterioration of market liquidity, increase the risk of counterparty default, affect the regulatory and legislative process in unpredictable ways, negatively affect wholesale energy prices and/or impede PSE's ability to manage its energy portfolio risks and procure energy supply, affect the availability and access to capital and credit markets and/or impact delivery of energy to PSE from its suppliers;
●			Financial difficulties of other energy companies and related events, which may affect the regulatory and legislative process in unpredictable ways, adversely affect the availability of and access to capital and credit markets and/or impact delivery of energy to PSE from its suppliers;
●			The effect of wholesale market structures (including, but not limited to, regional market designs or transmission organizations) or other related federal initiatives;
●			PSE electric or natural gas distribution systems failure, blackouts or large curtailments of transmission or distribution systems (whether PSE's or others'), or failure of the interstate natural gas pipeline delivering to PSE's system, all of which can affect PSE's ability to deliver power or natural gas to its customers and generating facilities;
●			Electric plant generation and transmission system outages, which can have an adverse impact on PSE's expenses with respect to repair costs, added costs to replace energy or higher costs associated with dispatching a more expensive generation resource;
●			The ability to restart generation following a regional transmission disruption;
●			The ability of a natural gas or electric plant to operate as intended;
●			PSE's resource adequacy needs to meet the Washington Clean Energy Transformation Act (CETA) and the Washington Climate Commitment Act (CCA) requirements, through a combination of owned or contracted resources, may significantly increase purchased power and gas costs if pricing pressures and supply constraints on resource acquisitions increase;
●			Changes in climate, weather conditions, or sustained extreme weather events in PSE's operational territory, which could have effects on customer usage and PSE's revenue and expenses;
●			Regional or national weather conditions (including conditions and events associated with climate change), wildfires, droughts, earthquakes, and other natural disasters, which could impact PSE's ability to procure adequate supplies of natural gas, fuel or purchased power to serve its customers and the cost of procuring such supplies;
●			Variable hydrological conditions, which can impact streamflow and PSE's ability to generate electricity from hydroelectric facilities;
●			Variable wind conditions, which can impact PSE's ability to generate electricity from wind facilities;
●			The ability to renew contracts for electric and natural gas supply and the price and terms of renewal;
●			Industrial, commercial and residential growth and demographic patterns in the service territories of PSE;
●			General economic conditions in the Pacific Northwest, such as inflation, which may impact customer consumption or affect PSE's accounts receivable;
●			The loss of significant customers, changes in the business of significant customers or the condemnation of PSE's facilities as a result of municipalization or other government action or negotiated settlement, which may result in changes in demand for PSE's services;
●			The failure of information systems or the failure to secure information system data, which may impact the operations and cost of PSE's customer service, generation, distribution and transmission;
●			Opposition and social activism that may hinder PSE's ability to perform work or construct infrastructure;
●			Capital market conditions, including changes in the availability of capital and interest rate fluctuations;
●			General economic and political conditions, such as the effects of geopolitical tensions related to the ongoing Russia-Ukraine and Middle East conflicts, recessions, tariffs and trade restrictions, fuel prices, international currency fluctuations, sanctions, corruption, political instability, acts of war and local and national elections;
●			Employee workforce factors including strikes; work stoppages; retirements; absences due to pandemics, accidents, natural disasters or other significant, unforeseeable events; and availability of qualified employees or the loss of a key executive;
●			PSE's ability to attract, retain, and compensate employees while operating within a region of high demand for skilled workers resulting in significant competition and wage pressure;
●			The ability to obtain insurance coverage, the availability of insurance for certain specific losses, including those arising from catastrophic events such as wildfires and the cost of such insurance;
●			Changes in Puget Energy's or PSE's credit ratings, which may have an adverse impact on the availability and cost of capital for Puget Energy or PSE generally and the ability to pay dividends;
●			Deteriorating values of the equity, fixed income and other markets which could significantly impact the value of investments of PSE's retirement plan, post-retirement medical benefit plan trusts and the funding of obligations thereunder; and
●			Recent laws enacted, amended or proposed in Washington and other municipalities in PSE's service territory, which may impact PSE’s operations by, among others: changing system planning; changing existing statutory targets; instituting electrification requirements; or establishing Washington Commission requirements.

Any forward-looking statement speaks only as of the date on which such statement is made, and, except as required by law, the Company undertakes no obligation to update any forward-looking statement to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time and it is not possible for management to predict all such factors, nor can it assess the impact of any such factor on the business or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forward-looking statement. For further information, see Part I, Item 1A, “Risk Factors” in the Company's most recent Annual Report on Form 10-K for the year ended December 31, 2024.

PART I FINANCIAL INFORMATION

Item 1. Financial Statements

PUGET ENERGY, INC.

CONSOLIDATED STATEMENTS OF INCOME

(Dollars in Thousands)

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Operating revenue:
Electric	$	832,355	$	709,829	$	1,859,303	$	1,698,345
Natural gas	270,370		276,935		835,297		834,359
Other	17,740		7,204		27,868		15,681
Total operating revenue	1,120,465		993,968		2,722,468		2,548,385
Operating expenses:
Energy costs:
Purchased electricity	276,118		255,849		657,646		641,614
Electric generation fuel	71,608		45,431		163,232		162,988
Residential exchange	(17,367)		(17,855)		(44,601)		(44,153)
Purchased natural gas	97,484		133,180		343,999		404,533
Unrealized (gain) loss on derivative instruments, net	—		7,068		—		22,733
Utility operations and maintenance	207,957		192,665		440,342		395,782
Non-utility expense and other	17,414		11,497		32,741		22,440
Depreciation & amortization	209,536		195,466		419,912		387,342
Conservation amortization	36,307		29,657		84,187		67,489
Taxes other than income taxes	96,990		89,046		239,711		215,357
Total operating expenses	996,047		942,004		2,337,169		2,276,125
Operating income (loss)	124,418		51,964		385,299		272,260
Other income (expense):
Other income	39,047		24,953		72,311		41,934
Other expense	(14,936)		(8,042)		(18,452)		(10,145)
Interest charges:
AFUDC	10,911		8,981		20,998		18,068
Interest expense	(116,201)		(106,836)		(228,863)		(209,284)
Income (loss) before income taxes	43,239		(28,980)		231,293		112,833
Income tax (benefit) expense	(935)		96		19,563		12,000
Net income (loss)	$	44,174	$	(29,076)	$	211,730	$	100,833

The accompanying notes are an integral part of the financial statements.

PUGET ENERGY, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Dollars in Thousands)

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Net income (loss)	$	44,174	$	(29,076)	$	211,730	$	100,833
Other comprehensive income (loss):
Net unrealized gain (loss) from pension and postretirement plans, net of tax of $(269), $(147), $(538) and $1,547, respectively	(1,012)		(553)		(2,026)		(2,952)



Other comprehensive income (loss)	(1,012)		(553)		(2,026)		(2,952)
Comprehensive income (loss)	$	43,162	$	(29,629)	$	209,704	$	97,881

The accompanying notes are an integral part of the financial statements.

PUGET ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(Dollars in Thousands)

(Unaudited)

ASSETS


	June 30, 2025		December 31, 2024
Utility plant (at original cost, including construction work in progress of $1,936,025 and $1,577,695 respectively):
Electric plant	$	12,979,806	$	12,476,380
Natural gas plant	5,299,705		5,178,523
Common plant	1,135,299		1,089,618
Less: Accumulated depreciation and amortization	(5,355,083)		(5,101,926)
Net utility plant	14,059,727		13,642,595
Other property and investments:
Goodwill	1,656,513		1,656,513
Other property and investments	297,533		307,813
Total other property and investments	1,954,046		1,964,326
Current assets:
Cash and cash equivalents	52,035		101,836
Restricted cash	106,411		38,865
Accounts receivable, net of allowance for doubtful accounts of $46,064 and $40,436, respectively	488,537		538,930
Unbilled revenue	211,691		273,420

Materials and supplies, at average cost	235,932		201,847
Fuel and natural gas inventory, at average cost	78,333		88,964
Unrealized gain on derivative instruments	29,025		32,591
GHG emission allowances	250		43,592
Prepaid expense and other	62,764		83,851
Power contract acquisition adjustment gain	3,844		4,122
Total current assets	1,268,822		1,408,018
Other long-term and regulatory assets:


Power cost adjustment mechanism	113,927		61,202

Regulatory assets related to power contracts	4,230		4,779
Other regulatory assets	1,126,142		1,355,291
Unrealized gain on derivative instruments	23,078		6,245
Power contract acquisition adjustment gain	24,660		26,444
Operating lease right-of-use asset	345,916		181,397
Other	315,773		310,094
Total other long-term and regulatory assets	1,953,726		1,945,452
Total assets	$	19,236,321	$	18,960,391

The accompanying notes are an integral part of the financial statements.

PUGET ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(Dollars in Thousands)

(Unaudited)

CAPITALIZATION AND LIABILITIES


	June 30, 2025		December 31, 2024
Capitalization:
Common shareholder’s equity:
Common stock $0.01 par value, 1,000 shares authorized, 200 shares outstanding	$	—	$	—
Additional paid-in capital	3,816,332		3,816,332
Retained earnings	1,697,061		1,508,705
Accumulated other comprehensive income (loss), net of tax	41,142		43,168
Total common shareholder’s equity	5,554,535		5,368,205
Long-term debt:
First mortgage bonds and senior notes	5,845,000		5,845,000
Pollution control bonds	161,860		161,860

Long-term debt	2,200,000		1,600,000
Debt discount issuance costs and other	(182,350)		(182,941)
Total long-term debt	8,024,510		7,423,919
Total capitalization	13,579,045		12,792,124
Current liabilities:
Accounts payable	428,062		549,710
Short-term debt	363,000		378,400
Current maturities of long-term debt	17,000		417,000

Accrued expenses:
Taxes	90,634		105,080
Salaries and wages	56,854		74,294
Interest	74,211		66,113
Unrealized loss on derivative instruments	117,862		218,443
Power contract acquisition adjustment loss	1,019		1,074
Operating lease liabilities	90,553		22,761
Compliance obligation	—		43,592
Other	101,732		105,605
Total current liabilities	1,340,927		1,982,072
Other long-term and regulatory liabilities:
Deferred income taxes	1,028,368		997,680
Unrealized loss on derivative instruments	98,371		171,488
Purchased gas adjustment liability	93,780		58,657
Regulatory liabilities	1,043,893		1,075,620
Regulatory liability for deferred income taxes	695,575		721,907
Regulatory liabilities related to power contracts	28,504		30,566
Power contract acquisition adjustment loss	3,211		3,705
Operating lease liabilities	262,827		166,700
Finance lease liabilities	94,691		96,850
Compliance obligation	149,752		73,049
Other deferred credits	817,377		789,973
Total long-term and regulatory liabilities	4,316,349		4,186,195
Commitments and contingencies (Note 8)
Total capitalization and liabilities	$	19,236,321	$	18,960,391

(Dollars in Thousands)

(Unaudited)


	Six Months Ended June 30,
	2025		2024
Operating activities:
Net Income (loss)	$	211,730	$	100,833
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	419,912		387,342
Conservation amortization	84,187		67,489
Deferred income taxes and tax credits, net	4,895		(11,272)
Net unrealized (gain) loss on derivative instruments	—		22,733


AFUDC - equity	(36,476)		(24,222)

Other non-cash	33,061		20,184


Regulatory assets and liabilities	(37,628)		8,593
Purchased gas adjustment	35,123		(50,722)
GHG emission allowances	(90,587)		(60,565)
Other long-term assets and liabilities	8,063		(3,397)
Change in certain current assets and liabilities:
Accounts receivable and unbilled revenue	112,122		142,739
Materials and supplies	(34,085)		(17,781)
Fuel and natural gas inventory	8,690		452
Prepayments and other	20,723		30,230

Accounts payable	(126,327)		(97,365)
Taxes payable	(14,446)		(13,806)
Other	(22,648)		(23,530)
Net cash provided by (used in) operating activities	576,309		477,935
Investing activities:
Construction expenditures - excluding equity AFUDC	(730,325)		(716,983)
Other	4,339		344
Net cash provided by (used in) investing activities	(725,986)		(716,639)
Financing activities:
Change in short-term debt, net	(15,400)		(243,300)
Dividends paid	(23,374)		(140,941)
Investment from Parent	—		292,800
Proceeds from long-term debt and bonds issued	596,100		793,892
Redemption of bonds and notes	(400,000)		—

Other	10,096		11,822
Net cash provided by (used in) financing activities	167,422		714,273
Net increase (decrease) in cash, cash equivalents, and restricted cash	17,745		475,569
Cash, cash equivalents, and restricted cash at beginning of period	140,701		214,575
Cash, cash equivalents, and restricted cash at end of period	$	158,446	$	690,144
Supplemental cash flow information:
Cash payments for interest (net of capitalized interest)	$	191,848	$	180,182
Cash payments (refunds) for income taxes	18,554		25,924
Non-cash financing and investing activities:
Accounts payable for capital expenditures eliminated from cash flows	$	113,429	$	90,809

The accompanying notes are an integral part of the financial statements.

PUGET SOUND ENERGY, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Dollars in Thousands)

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Net income (loss)	$	68,320	$	(3,284)	$	254,334	$	144,615
Other comprehensive income(loss):
Net unrealized gain (loss) from pension and postretirement plans, net of tax of $(17), $(7), $(35) and $1,825, respectively.	(66)		(35)		(131)		(1,906)


Amortization of treasury interest rate swaps to earnings, net of tax of $27, $26, $53 and $51, respectively.	95		96		192		193

Other comprehensive income (loss)	29		61		61		(1,713)
Comprehensive income (loss)	$	68,349	$	(3,223)	$	254,395	$	142,902

The accompanying notes are an integral part of the financial statements.

PUGET SOUND ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(Dollars in Thousands)

(Unaudited)

ASSETS


	June 30, 2025		December 31, 2024
Utility plant (at original cost, including construction work in progress of $1,936,025 and $1,577,695, respectively):
Electric plant	$	14,677,051	$	14,188,252
Natural gas plant	5,846,604		5,726,641
Common plant	1,155,562		1,110,364
Less: Accumulated depreciation and amortization	(7,619,490)		(7,382,662)
Net utility plant	14,059,727		13,642,595
Other property and investments:

Other property and investments	65,564		71,005
Total other property and investments	65,564		71,005
Current assets:
Cash and cash equivalents	51,043		100,105
Restricted cash	106,411		38,865
Accounts receivable, net of allowance for doubtful accounts of $46,064 and $40,436, respectively	488,044		539,072
Unbilled revenue	211,691		273,420

Materials and supplies, at average cost	235,932		201,847
Fuel and natural gas inventory, at average cost	76,920		87,118
Unrealized gain on derivative instruments	29,025		32,591
GHG emission allowances	250		43,592
Prepaid expense and other	62,651		83,835

Total current assets	1,261,967		1,400,445
Other long-term and regulatory assets:


Power cost adjustment mechanism	113,927		61,202


Other regulatory assets	1,126,142		1,355,291
Unrealized gain on derivative instruments	23,078		6,245

Operating lease right-of-use asset	345,916		181,397
Other	314,497		308,204
Total other long-term and regulatory assets	1,923,560		1,912,339
Total assets	$	17,310,818	$	17,026,384

The accompanying notes are an integral part of the financial statements.

PUGET SOUND ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(Dollars in Thousands)

(Unaudited)

CAPITALIZATION AND LIABILITIES


	June 30, 2025		December 31, 2024
Capitalization:
Common shareholder’s equity:
Common stock $0.01 par value, 150,000,000 shares authorized, 85,903,791 shares outstanding	$	859	$	859
Additional paid-in capital	4,066,905		3,927,905
Retained earnings	1,894,911		1,665,370
Accumulated other comprehensive income (loss), net of tax	(30,186)		(30,247)
Total common shareholder’s equity	5,932,489		5,563,887
Long-term debt:
First mortgage bonds and senior notes	5,845,000		5,845,000
Pollution control bonds	161,860		161,860

Debt discount, issuance costs and other	(44,544)		(45,835)
Total long-term debt	5,962,316		5,961,025
Total capitalization	11,894,805		11,524,912
Current liabilities:
Accounts payable	428,066		550,765
Short-term debt	55,000		40,000
Current maturities of long-term debt	17,000		17,000

Accrued expenses:
Taxes	91,035		105,754
Salaries and wages	56,854		74,294
Interest	55,809		56,215
Unrealized loss on derivative instruments	117,862		218,443

Operating lease liabilities	90,553		22,761
Compliance obligation	—		43,592
Other	101,732		105,605
Total current liabilities	1,013,911		1,234,429
Other long-term and regulatory liabilities:
Deferred income taxes	1,150,619		1,117,492
Unrealized loss on derivative instruments	98,371		171,488
Purchased gas adjustment liability	93,780		58,657
Regulatory liabilities	1,042,700		1,074,427
Regulatory liabilities for deferred income tax	696,214		722,558


Operating lease liabilities	262,827		166,700
Finance lease liabilities	94,691		96,850
Compliance obligation	149,752		73,049
Other deferred credits	813,148		785,822
Total long-term and regulatory liabilities	4,402,102		4,267,043
Commitments and contingencies (Note 8)
Total capitalization and liabilities	$	17,310,818	$	17,026,384

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Dollars in Thousands)

(Unaudited)


	Six Months Ended June 30,
	2025		2024
Operating activities:
Net Income (loss)	$	254,334	$	144,615
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	416,545		384,006
Conservation amortization	84,187		67,489
Deferred income taxes and tax credits, net	6,767		(22,660)
Net unrealized (gain) loss on derivative instruments	—		22,733

AFUDC - equity	(36,476)		(24,222)

Other non-cash	25,863		14,932


Regulatory assets and liabilities	(37,628)		8,593
Purchased gas adjustment	35,123		(50,722)
GHG emission allowances	(90,587)		(60,565)
Other long-term assets and liabilities	10,200		(2,066)
Change in certain current assets and liabilities:
Accounts receivable and unbilled revenue	112,757		143,010
Materials and supplies	(34,085)		(17,781)
Fuel and natural gas inventory	8,257		30
Prepayments and other	20,820		30,322

Accounts payable	(127,378)		(99,387)
Taxes payable	(14,719)		(13,448)
Other	(31,155)		(23,746)
Net cash provided by (used in) operating activities	602,825		501,133
Investing activities:
Construction expenditures - excluding equity AFUDC	(730,046)		(716,606)
Other	4,339		344
Net cash provided by (used in) investing activities	(725,707)		(716,262)
Financing activities:
Change in short-term debt, net	15,000		(336,600)
Dividends paid	(24,793)		(69,339)
Investment from Parent	139,000		292,800
Proceeds from long-term debt and bonds issued	—		793,892

Other	12,159		11,816
Net cash provided by (used in) financing activities	141,366		692,569
Net increase (decrease) in cash, cash equivalents, and restricted cash	18,484		477,440
Cash, cash equivalents, and restricted cash at beginning of period	138,970		210,852
Cash, cash equivalents, and restricted cash at end of period	$	157,454	$	688,292
Supplemental cash flow information:
Cash payments for interest (net of capitalized interest)	$	146,414	$	129,747
Cash payments (refunds) for income taxes	29,615		47,283
Non-cash financing and investing activities:
Accounts payable for capital expenditures eliminated from cash flows	$	113,429	$	90,809

The accompanying notes are an integral part of the financial statements.

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

(1)Summary of Significant Accounting Policies

Basis of Presentation

Puget Energy is an energy services holding company that owns PSE, which 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, which has the sole purpose of owning and operating the non-regulated activity of the Tacoma 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, 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 FASB ASC 805, “Business Combinations” (ASC 805), as of the date of the merger. ASC 805 requires the acquirer to recognize and measure identifiable assets acquired and liabilities assumed at fair value as of the merger date.

The consolidated financial statements of Puget Energy reflect the accounts of Puget Energy and its 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 purchase accounting adjustments. The preparation of financial statements in conformity with U.S. 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

The Company 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 following table presents the activity in the allowance for credit losses for accounts receivable for the six months ended June 30, 2025 and 2024:


Puget Energy and Puget Sound Energy	Six Months Ended June 30,
(Dollars in Thousands)	2025		2024
Allowance for credit losses:
Beginning balance	$	40,436	$	38,211
Provision for credit loss expense1	27,001		23,690
Receivables charged-off	(21,373)		(22,316)

Total ending allowance balance	$	46,064	$	39,585

_____________

1 $17.7 million and $4.3 million of provision related to balances of deferred costs specific to COVID-19 as of June 30, 2025 and 2024, respectively.

Tacoma LNG Facility

Operational since February 2022, the Tacoma LNG facility at the Port of Tacoma provides peak-shaving services to PSE’s natural gas customers and provides LNG as fuel to transportation customers, particularly in the marine market. In December 2019, the Puget Sound Clean Air Agency (PSCAA) issued the air quality permit for the facility, and the Pollution Hearings Control Board of Washington State upheld the approval following extended litigation.

Pursuant to an order by the Washington Commission, approximately 43.0% of common capital and operating costs is allocated to PSE, the regulated portion of the Tacoma LNG facility. The remaining 57.0% of common capital and operating costs of the Tacoma LNG facility is allocated to Puget LNG, the unregulated portion of the Tacoma LNG facility. Per this

allocation of costs, $231.8 million and $234.8 million of net non-utility plant 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, 2025 and December 31, 2024, respectively. Additionally, $12.7 million and $11.3 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, 2025, and June 30, 2024, respectively. Further, $226.1 million and $229.0 million of natural gas plant 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, 2025 and December 31, 2024, respectively, as PSE is a regulated entity.

Variable Interest Entities

PSE has certain power purchase agreements (PPAs) in which PSE has variable interests mainly including fixed price contracts for renewable energy. The most significant economic activity for these variable interest entities (VIEs) is typically the operation and maintenance of the facility, which is performed by the seller. Therefore, the Company is not the primary beneficiary of any of these VIEs as it does not control the commercial and operating activities that most significantly impact the economic performance of the entities.

The carrying amount of any assets and liabilities related to these VIEs in the Company’s balance sheets represent amounts due from the PPAs. The Company can recover these costs through the PCA mechanism. The Company has no residual interest in the entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees, or other commitments associated with these contracts. The aggregate contracted capacity from these VIE projects was 723.8 MW at June 30, 2025 and 2024, and the amounts that the Company paid related to these VIEs were $45.7 million and $48.3 million for the six months ended June 30, 2025 and 2024, respectively.

For further information on the Company's accounting policies, see Part II, Item 8, Note 1, "Summary of Significant Accounting Policies" in the Company's Annual Report on Form 10-K for the year ended December 31, 2024.

(2) New Accounting Pronouncements

Recently Adopted Accounting Guidance

Reportable Segment Disclosures

In November 2023, the FASB issued ASU 2023-07, "Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures". ASU 2023-07 is intended to improve the disclosures for reportable segments and provide more detailed information about a reportable segment's expenses. This requires disclosure of significant segment expense categories, amounts for each reportable segment, disclosure of the title and position of the Chief Operating Decision Maker and how they use the measure of the segments' profit or loss to assess performance and allocate resources. ASU 2023-07 is effective for the Company in fiscal years beginning after December 15, 2023, and interim periods in fiscal years beginning after December 15, 2024. As of June 30, 2025, the Company's disclosures are consistent with the amendment.

Income Tax Disclosures

In December 2023, the FASB issued ASU 2023-09, "Income Taxes (Topic 740): Improvements to Income Tax Disclosures". ASU 2023-09 will require disclosure of specific categories in a tabular rate reconciliation using both percentages and currency amounts and provide additional information for reconciling items that meet a quantitative threshold. Further requirements include a qualitative description of the tax jurisdictions, an explanation of the reconciling items disclosed and disclosure regarding income taxes paid. ASU 2023-09 eliminates the requirement to disclose the nature and estimate of range in unrecognized tax benefits and disclosures of the cumulative amount of each type of temporary difference when a deferred tax liability is not recognized. ASU 2023-09 will be effective for the Company in annual periods beginning after December 15, 2024. As of June 30, 2025, the Company's disclosures are consistent with the amendment.

Accounting Standards Issued but Not Yet Adopted

Income Statement Reporting Comprehensive Income Disclosures

In November 2024, the FASB issued ASU 2024-03, "Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures". ASU 2024-03 will require disclosure of specific cost and expense information in the notes to the financial statements. Disclosure shall include inventory purchases, employee compensation, depreciation and intangible asset amortization presented in the face of the income statement for continuing operations. It shall also include certain amounts already disclosed under GAAP in the same disclosure as other disaggregation requirements as well as disclose a qualitative description and the amount of selling expenses. ASU 2024-03 will be effective for the Company in annual periods beginning

after December 15, 2026. The amendment contemplates changes in disclosures only and the Company continues to assess the impacts of the amendment.

(3) Revenue

The following tables present disaggregated revenue from contracts with customers, and other revenue by major source for the three months and six months ended June 30, 2025 and June 30, 2024:


Puget Energy and Puget Sound Energy
(Dollars in Thousands)	Three Months Ended June 30, 2025
Revenue from contracts with customers:	Electric		Natural Gas		Other1		Total
Retail
Residential	$	398,937	$	162,475	$	—	$	561,412
Commercial	294,602		83,876		—		378,478
Industrial	33,655		5,430		—		39,085
Other	5,032		—		—		5,032
Wholesale	63,080		—		—		63,080
Transmission and transportation	8,717		5,210		—		13,927
Miscellaneous2	8,780		15,782		17,740		42,302
Total revenue from contracts with customers	$	812,803	$	272,773	$	17,740	$	1,103,316
Total other revenue3	19,552		(2,403)		—		17,149
Total operating revenue	$	832,355	$	270,370	$	17,740	$	1,120,465

_____________

1 Other includes $10.4 million of Puget LNG revenues recorded at Puget Energy.

2 Miscellaneous natural gas revenue includes $15.7 million for the regulatory offset of CCA auction proceeds passed back to customers.

3 Total other revenue includes revenues from derivatives and alternative revenue programs that are not considered revenues from contracts with customers.


Puget Energy and Puget Sound Energy
(Dollars in Thousands)	Three Months Ended June 30, 2024
Revenue from contracts with customers:	Electric		Natural Gas		Other1		Total
Retail
Residential	$	351,048	$	150,708	$	—	$	501,756
Commercial	265,504		74,567		—		340,071
Industrial	32,074		5,699		—		37,773
Other	5,172		—		—		5,172
Wholesale	37,594		—		—		37,594
Transmission and transportation	8,284		6,372		—		14,656
Miscellaneous2	7,919		55,742		7,204		70,865
Total revenue from contracts with customers	$	707,595	$	293,088	$	7,204	$	1,007,887
Total other revenue3	2,234		(16,153)		—		(13,919)
Total operating revenue	$	709,829	$	276,935	$	7,204	$	993,968

_____________

1 Other includes $7.1 million of Puget LNG revenues recorded at Puget Energy.

2 Miscellaneous natural gas revenue includes $57.0 million for the regulatory offset of CCA auction proceeds passed back to customers.

3 Total other revenue includes revenues from derivatives and alternative revenue programs that are not considered revenues from contracts with customers.


Puget Energy and Puget Sound Energy
(Dollars in Thousands)	Six Months Ended June 30, 2025
Revenue from contracts with customers:	Electric		Natural Gas		Other1		Total
Retail
Residential	$	982,700	$	535,840	$	—	$	1,518,540
Commercial	635,910		243,357		—		879,267
Industrial	70,344		15,752		—		86,096
Other	11,274		—		—		11,274
Wholesale	135,072		—		—		135,072
Transmission and transportation	17,481		13,498		—		30,979
Miscellaneous2	14,402		56,674		27,868		98,944
Total revenue from contracts with customers	1,867,183		865,121		27,868		2,760,172
Total other revenue3	(7,880)		(29,824)		—		(37,704)
Total operating revenue	$	1,859,303	$	835,297	$	27,868	$	2,722,468

__________________

1 Other includes $20.4 million of Puget LNG revenues recorded at Puget Energy.

2 Miscellaneous natural gas revenue includes $53.6 million for the regulatory offset of CCA auction proceeds passed back to customers.

3 Total other revenue includes revenues from derivatives and alternative revenue programs that are not considered revenues from contracts with customers.


Puget Energy and Puget Sound Energy
(Dollars in Thousands)	Six Months Ended June 30, 2024
Revenue from contracts with customers:	Electric		Natural Gas		Other1		Total
Retail
Residential	$	860,470	$	444,005	$	—	$	1,304,475
Commercial	576,089		200,454		—		776,543
Industrial	66,116		14,867		—		80,983
Other	11,790		—		—		11,790
Wholesale	155,111		—		—		155,111
Transmission and transportation	19,323		15,710		—		35,033
Miscellaneous2	12,213		159,304		15,681		187,198
Total revenue from contracts with customers	1,701,112		834,340		15,681		2,551,133
Total other revenue3	(2,767)		19		—		(2,748)
Total operating revenue	$	1,698,345	$	834,359	$	15,681	$	2,548,385

__________________

1 Other includes $15.5 million of Puget LNG revenues recorded at Puget Energy.

2 Miscellaneous natural gas revenue includes $164.8 million for the regulatory offset of CCA auction proceeds passed back to customers.

3 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 which began April 1, 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.

The Company expects to recognize revenue over the following time periods:


Puget Energy
(Dollars in Thousands)	2025		2026		2027		2028		2029		Thereafter		Total
Remaining performance obligations	$	9,364	$	19,315	$	19,454	$	19,454	$	19,454	$	82,681	$	169,722

The Company has elected the optional exemption in ASC 606, "Revenues from Contracts with Customers", under which the Company does not disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. The primary sources of variability are (a) fluctuations in market index prices of natural gas used to determine aspects of variable pricing and (b) variation in volumes that may be delivered to the customer. Both sources of variability are expected to be resolved at or shortly before delivery of each unit of LNG or natural gas. As each unit of LNG or natural gas represents a separate performance obligation, future volumes are wholly unsatisfied.

(4) 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. 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 Puget Sound Energy
	June 30, 2025					December 31, 2024
(Dollars in Thousands)	Volumes (millions)	Assets1		Liabilities2		Volumes (millions)	Assets1		Liabilities2
Electric portfolio derivatives3	*	$	36,351	$	179,888	*	$	35,341	$	319,506
Natural gas derivatives (MMBtus)3	250	15,752		36,345		269	3,495		70,425
Total derivative contracts		$	52,103	$	216,233		$	38,836	$	389,931
Current		$	29,025	$	117,862		$	32,591	$	218,443
Long-term		23,078		98,371			6,245		171,488
Total derivative contracts		$	52,103	$	216,233		$	38,836	$	389,931

_______________

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 have been deferred in accordance with ASC 980, “Regulated Operations.” The net derivative asset or liability and offsetting regulatory liability or asset are related to contracts used to economically hedge the cost of electricity and physical gas purchased to serve customers.

* Electric portfolio derivatives consist of electric generation fuel of 288.8 million MMBtu and purchased electricity of 12.1 million MWhs at June 30, 2025, and 283.5 million MMBtus and 13.3 million MWhs at December 31, 2024.

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 agreements, which standardize physical power contracts; ISDA agreements, which standardize financial natural gas and electric contracts; and 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," in the Combined Notes to Consolidated Financial Statements included in Item 1 of this report.

The electric and natural gas derivative contracts above will be included in power costs during the period they are delivered and will be included in the applicable recovery mechanism.

The following tables present the potential effect of netting arrangements, including rights of set-off associated with the Company's derivative assets and liabilities:


Puget Energy and Puget Sound Energy
	At June 30, 2025
	Gross Amount Recognized in the Statement of Financial Position1		Gross Amounts Offset in the Statement of Financial Position		Net of Amounts Presented in the Statement of Financial Position		Gross Amounts Not Offset in the Statement of Financial Position
(Dollars in Thousands)							Commodity Contracts		Cash Collateral Received/Posted		Net Amount
Assets:
Energy derivative contracts	$	52,103	$	—	$	52,103	$	(45,955)	$	—	$	6,148
Liabilities:
Energy derivative contracts	$	216,233	$	—	$	216,233	$	(45,955)	$	(10,778)	$	159,500



Puget Energy and Puget Sound Energy	At December 31, 2024
	Gross Amount Recognized in the Statement of Financial Position1		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	$	38,836	$	—	$	38,836	$	(34,329)	$	—	$	4,507
Liabilities:
Energy derivative contracts	$	389,931	$	—	$	389,931	$	(34,329)	$	(3,593)	$	352,009

_______________

1 All derivative contract deals are executed under ISDA, NAESB, and WSPP master agreements with right of set-off.

On December 19, 2024, the Washington Commission approved the Company's accounting petition in Docket No. UE-240773 to defer any incurred unrealized gains or losses on derivative instruments entered into to serve electric customers, and as such PSE has recognized regulatory assets and/or liabilities, thus deferring the unrealized gains or losses. The Company recognized an unrealized loss of $7.1 million and $22.7 million related to its derivatives in the three and six months ended June 30, 2024, respectively in the 'Unrealized gain (loss) on derivative instruments, net' line item on its Consolidated Statements of Income. For further information see Part I, Item I, Note 4 "Accounting for Derivative Instruments and Hedging Activities" in the Company’s Quarterly Report on Form 10-Q for the period ended June 30, 2024 and Part II, Item 8, Note 10, "Accounting for Derivative Instruments and Hedging Activities" in the Company’s Annual Report on Form 10-K for the year ended December 31, 2024.

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, 2025, approximately 99.4% of the Company's energy portfolio exposure, excluding NPNS transactions, is with counterparties that are rated investment grade by rating agencies and 0.6% is 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, 2025, PSE had cash posted as collateral of $20.2 million related to contracts executed on the ICE platform. As a condition of transacting on the ICE NGX platform as well as

participating in the Washington state carbon allowance auctions, PSE maintains a standby letter of credit agreement with TD Bank. As of June 30, 2025, PSE had no cash posted with ICE NGX, and $5.1 million was issued under the standby letter of credit agreement in support of natural gas and carbon allowance purchases. 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 six months ended June 30, 2025.

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 Puget Sound Energy
(Dollars in Thousands)	At June 30, 2025						At December 31, 2024
	Fair Value1		Posted		Contingent		Fair Value1		Posted		Contingent
Contingent Feature	Liability		Collateral		Collateral		Liability		Collateral		Collateral
Credit rating2	$	106,686	$	—	$	106,686	$	179,532	$	—	$	179,532
Requested credit for adequate assurance	18,760		—		—		37,492		—		—
Forward value of contract3	11,402		20,182		N/A		19,905		12,915		N/A
Total	$	136,848	$	20,182	$	106,686	$	236,929	$	12,915	$	179,532

_______________

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.

(5) 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. The Company’s environmental compliance obligation is categorized in Level 2 of the fair value hierarchy and is measured at fair value using a market approach based on quoted prices from an independent pricing service.

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. Investments in life insurance contracts of $44.3 million and $44.8 million at June 30, 2025 and December 31, 2024 respectively, are included in "Other property and investments" on the balance sheet. These investments are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts.

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, 2025				December 31, 2024
(Dollars in Thousands)	Level	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities:
Long-term debt (fixed-rate), net of discount1	2	$	8,024,510	$	7,654,266	$	7,423,919	$	6,966,211
Total liabilities		$	8,024,510	$	7,654,266	$	7,423,919	$	6,966,211


Puget Sound Energy		June 30, 2025				December 31, 2024
(Dollars in Thousands)	Level	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities:
Long-term debt (fixed-rate), net of discount2	2	$	5,962,316	$	5,545,068	$	5,961,025	$	5,492,999
Total liabilities		$	5,962,316	$	5,545,068	$	5,961,025	$	5,492,999

_______________

1 The carrying value includes debt issuances costs of $22.4 million and $21.3 million for June 30, 2025 and December 31, 2024, respectively, which are not included in fair value.

2 The carrying value includes debt issuances costs of $21.3 million and $22.1 million for June 30, 2025 and December 31, 2024, 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 Puget Sound Energy	Fair Value At June 30, 2025						Fair Value At December 31, 2024
(Dollars in Thousands)	Level 2		Level 3		Total		Level 2		Level 3		Total
Assets:
Electric derivative instruments	$	22,148	$	14,204	$	36,352	$	25,236	$	10,105	$	35,341
Natural gas derivative instruments	10,990		4,761		15,751		1,729		1,766		3,495
Total assets	$	33,138	$	18,965	$	52,103	$	26,965	$	11,871	$	38,836
Liabilities:
Electric derivative instruments	$	72,320	$	107,568	$	179,888	$	134,292	$	185,214	$	319,506
Natural gas derivative instruments	36,122		223		36,345		70,050		375		70,425
Compliance obligations	149,752		—		149,752		73,049		—		73,049
Total liabilities	$	258,194	$	107,791	$	365,985	$	277,391	$	185,589	$	462,980

The following tables present the Company's reconciliation of the changes in the fair value of Level 3 derivatives in the fair value hierarchy:


Puget Energy and Puget Sound Energy	Three Months Ended June 30,
(Dollars in Thousands)	2025						2024
Level 3 Roll-Forward Net Asset/(Liability)	Electric		Natural Gas		Total		Electric		Natural Gas		Total
Balance at beginning of period	$	(203,718)	$	1,585	$	(202,133)	$	3,565	$	3,397	$	6,962
Changes during period:
Realized and unrealized energy derivatives:
Included in earnings1	—		—		—		(6,881)		—		(6,881)
Included in regulatory assets / liabilities	102,904		3,407		106,311		—		65		65
Settlements	7,450		(454)		6,996		6,357		(1,440)		4,917
Transferred into Level 3	—		—		—		—		—		—
Transferred out of Level 3	—		—		—		—		—		—
Balance at end of period	$	(93,364)	$	4,538	$	(88,826)	$	3,041	$	2,022	$	5,063

_______________

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 $(6.6) million for the three months ended June 30, 2024.


Puget Energy and Puget Sound Energy	Six Months Ended June 30,
(Dollars in Thousands)	2025						2024
Level 3 Roll-Forward Net Asset/(Liability)	Electric		Natural Gas		Total		Electric		Natural Gas		Total
Balance at beginning of period	$	(175,110)	$	1,391	$	(173,719)	$	27,262	$	3,851	$	31,113
Changes during period:
Realized and unrealized energy derivatives:
Included in earnings1	—		—		—		(50,898)		—		(50,898)
Included in regulatory assets / liabilities	44,419		4,024		48,443		—		524		524
Settlements	37,327		(877)		36,450		26,677		(2,353)		24,324
Transferred into Level 3	—		—		—		—		—		—
Transferred out of Level 3	—		—		—		—		—		—
Balance at end of period	$	(93,364)	$	4,538	$	(88,826)	$	3,041	$	2,022	$	5,063

_______________

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 $(41.0) million for the six months ended June 30, 2024.

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 natural 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, 2025:


Puget Energy and Puget Sound Energy	Fair Value						Range
(Dollars in Thousands)	Assets1		Liabilities1		Valuation Technique	Unobservable Input	Low		High		Weighted Average
Electric	$	14,204	$	107,568	Discounted cash flow	Power prices (per MWh)	$	29.85	$	139.93	$	70.90
Natural gas	$	4,761	$	223	Discounted cash flow	Natural gas prices (per MMBtu)	$	0.45	$	5.80	$	2.79

_______________

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, 2024:


Puget Energy and Puget Sound Energy	Fair Value						Range
(Dollars in Thousands)	Assets1		Liabilities1		Valuation Technique	Unobservable Input	Low		High		Weighted Average
Electric	$	10,104	$	185,214	Discounted cash flow	Power prices (per MWh)	$	13.82	$	138.94	$	64.59
Natural gas	$	1,767	$	376	Discounted cash flow	Natural gas prices (per MMBtu)	$	2.66	$	4.17	$	3.66

_______________

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, 2025 and December 31, 2024, 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 $62.1 million and $57.8 million, respectively.

(6) Retirement Benefits

The following tables summarize the Company’s net periodic benefit cost for the three and six months ended June 30, 2025 and 2024:


Puget Energy	Qualified Pension Benefits				SERP Pension Benefits				Other Benefits
	Three Months Ended June 30,
(Dollars in Thousands)	2025		2024		2025		2024		2025		2024
Components of net periodic benefit cost:
Service cost	$	4,206	$	4,784	$	—	$	—	$	51	$	50
Interest cost	8,054		7,790		307		342		108		104
Expected return on plan assets	(14,061)		(13,731)		—		2		(73)		(77)
Amortization of prior service cost	—		—		—		—		9		8
Amortization of net loss (gain)	(1,196)		(682)		(50)		(11)		(46)		(40)
Net periodic benefit cost	$	(2,997)	$	(1,839)	$	257	$	333	$	49	$	45


Puget Energy	Qualified Pension Benefits				SERP Pension Benefits				Other Benefits
	Six Months Ended June 30,
(Dollars in Thousands)	2025		2024		2025		2024		2025		2024
Components of net periodic benefit cost:
Service cost	$	8,412	$	9,308	$	—	$	—	$	102	$	100
Interest cost	16,107		15,576		613		685		217		208
Expected return on plan assets	(28,122)		(27,448)		—		2		(146)		(156)
Amortization of prior service cost	—		—		—		—		17		17
Amortization of net loss (gain)	(2,391)		(1,344)		(99)		(21)		(91)		(79)
Net periodic benefit cost	$	(5,994)	$	(3,908)	$	514	$	666	$	99	$	90


Puget Sound Energy	Qualified Pension Benefits				SERP Pension Benefits				Other Benefits

	Three Months Ended June 30,
(Dollars in Thousands)	2025		2024		2025		2024		2025		2024
Components of net periodic benefit cost:
Service cost	$	4,206	$	4,784	$	—	$	—	$	51	$	50
Interest cost	8,054		7,790		306		342		108		104
Expected return on plan assets	(14,061)		(13,731)		—		—		(72)		(77)
Amortization of prior service cost	—		—		—		—		9		8
Amortization of net loss (gain)	—		—		(45)		(5)		(47)		(41)
Net periodic benefit cost	$	(1,801)	$	(1,157)	$	261	$	337	$	49	$	44


Puget Sound Energy	Qualified Pension Benefits				SERP Pension Benefits				Other Benefits

	Six Months Ended June 30,
(Dollars in Thousands)	2025		2024		2025		2024		2025		2024
Components of net periodic benefit cost:
Service cost	$	8,412	$	9,308	$	—	$	—	$	102	$	100
Interest cost	16,107		15,576		613		685		217		208
Expected return on plan assets	(28,122)		(27,448)		—		2		(145)		(155)
Amortization of prior service cost	—		—		—		—		17		17
Amortization of net loss (gain)	—		—		(89)		(13)		(94)		(82)
Net periodic benefit cost	$	(3,603)	$	(2,564)	$	524	$	674	$	97	$	88

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, 2025, are expected to be at least $18.0 million, $6.8 million and $0.2 million, respectively. The Company contributed $3.0 million and $1.0 million to fund the SERP during each of the six months ended June 30, 2025 and the six months ended June 30, 2024, respectively. In addition, the Company contributed an immaterial amount to fund the other postretirement plans.

For further information, see Part II, Item 8, Note 13, "Retirement Benefits" in the Company's Annual Report on Form 10-K for the year ended December 31, 2024.

(7) Regulation and Rates

General Rate Case

PSE filed a GRC which includes a two-year MYRP with the Washington Commission on February 15, 2024. On January 15, 2025, the Washington Commission issued an order on PSE's 2024 GRC, in Docket Nos. UE-240004 and UG-240005, that approved a weighted cost of capital of 7.52% in 2025 and 7.64% in 2026, a capital structure of 49.0% in common equity in 2025 and 50.0% in 2026, and a return on equity of 9.8% in 2025 and 9.9% in 2026. On January 28, 2025, the Washington Commission approved PSE's electric and natural gas rates in its compliance filing with an overall net revenue change for electric of $378.2 million or 13.3% in 2025 and $191.0 million or 5.9% in 2026 and an overall net revenue change for natural gas of $110.0 million or 10.6% in 2025 and $20.0 million or 1.8% in 2026, with an effective date of January 29, 2025. PSE filed a petition for reconsideration on January 24, 2025 and multiple parties filed petitions for reconsideration and a motion for clarification on January 27, 2025. On March 17, 2025, the Washington Commission issued an order denying PSE’s petition for reconsideration. The order also granted and denied certain petitions for reconsideration and clarification by other parties. The order approved PSE's Targeted Electrification Pilot Phase II.

Liquefied Natural Gas Rate Adjustment

On April 24, 2024, the Washington Commission issued Final Order 07 in Docket No. UG-230393. The order determined that PSE acted prudently in developing and constructing the Tacoma LNG Facility after the initial decision to build in September 2016. Further, there were two main outcomes that resulted from the order. First, the Washington Commission did not authorize recovery of the portion of the Company’s deferred return on its investment in the Tacoma LNG Facility that was recorded between February 1, 2022, the date the facility was placed into service, and January 11, 2023, the date PSE’s 2022 GRC rates went into effect. Second, the Washington Commission directed PSE to increase the allocation of distribution pipeline investment to Puget LNG. The Washington Commission determined that the allocation should be tied to the relative flow of natural gas across these facilities, resulting in a higher allocation to Puget LNG than was originally filed. On May 3, 2024, PSE made the compliance filing required by Final Order 07. On May 24, 2024, Public Counsel and the Puyallup Tribe of Indians each filed a petition for judicial review of the Washington Commission’s Final Order 07. The petitions were filed in Thurston County Superior Court and were consolidated. Both petitions allege that the Washington Commission (i) failed to properly apply the updated public interest standard, (ii) failed to disallow all costs related to PSE’s redesign of the pipeline and development of waste gas disposal methods, and (iii) failed to conduct an independent determination of reasonable attorney fees. The parties agreed to seek direct review of the case by the Washington State Court of Appeals. The case was transferred to Division III of the Court of Appeals in March 2025 and briefing is underway.

PCA and PGA Unrealized Loss

On December 19, 2024, the Washington Commission approved the Company's accounting petition in Docket No. UE-240773 to offset any derivative assets or liabilities, entered into in order to serve electric customers, with a regulatory asset or liability, thus deferring the unrealized gains or losses. For additional information, see Note 4, "Accounting for Derivative Instruments and Hedging Activities" in the Combined Notes to Consolidated Financial Statements included in Item 1 of this report.

Climate Commitment Act Deferral

In 2023, PSE filed its initial revision to natural gas rates for the recovery of allowance costs and pass back of auction proceeds in Docket UG-230968. In this filing, PSE sought to update rates pertaining to amounts deferred from January 2023 through September 2023 and to add new language to the tariff that would enable PSE to fund decarbonization projects using a portion of its projected no cost allowances revenues. Subsequent filings were also made to revise the tariff rates for allowance costs and auction proceeds related to subsequent periods. The Washington Commission suspended the tariff sheets and subsequent updates but allowed the rates to go into effect on an interim basis, subject to refund, on January 1, 2024. The Washington Commission rejected all parties' proposals for gas utility risk sharing of CCA compliance costs, however indicated that it will consider whether a utility risk sharing mechanism is necessary in an ongoing rule making related to CCA implementation.

The ongoing recovery of allowance costs and pass back of proceeds from the sale of consigned no-cost allowances associated with PSE's natural gas business activities is consistent with the approved accounting petitions in Docket Nos. UG-220975 and UG-230471. As of June 30, 2025, PSE recorded a regulatory liability of $22.7 million, which represents the amounts to date collected in customer natural gas rates for CCA obligation costs, net of the expense incurred for the purchase of allowances for GHG emissions associated with the Company's electric and natural gas business activities. Additionally, PSE will continue to consign for auction at least the minimum amount of no-cost emission allowances allocated for natural gas business activities in compliance with the CCA, the proceeds of which will continue to be used for the benefit of natural gas customers, as determined by the Washington Commission. PSE does not record a regulatory liability to defer the proceeds until consigned allowances are sold at auction. As of June 30, 2025, PSE recorded a regulatory asset of $14.9 million, which represents the proceeds from the sale of consigned natural gas GHG emission allowances passed back through customer rates, net of proceeds received from the sale of consigned allowances sold at auction.

On May 2, 2025, PSE filed a revision to its electric tariff in Docket No. UE-250321, which proposed the establishment of a new schedule, Schedule 111E, which will allow PSE to recover the costs associated with its electric compliance obligation. PSE's proposal covered the recovery of its electric compliance costs incurred, or to be incurred, from January 2023 through December 2025, with a recovery period set for the period of August 1, 2025 through December 2026. On July 24, 2025, the Washington Commission approved the recovery of PSE's estimated 2023 and 2024 compliance costs and a pro-rata portion of the 2025 estimated compliance costs. The order also required PSE to file a proposal for future recovery of CCA costs, which must be made in PSE's next variable power cost filing update in October 2025.

Colstrip Adjustment Rider

On September 30, 2024, PSE filed proposed revisions to rates under the Colstrip Adjustment Rider Schedule 141COL with the Washington Commission, seeking to recover actual and forecasted costs for Colstrip Units 3 and 4 for calendar year 2025.

The proposed revisions would increase PSE's annual revenues by $4.1 million, or 0.1%. The Washington Commission Staff identified concerns regarding certain capital investments related to the Colstrip coal-fired generating facility, particularly in light of the CETA's mandate to remove coal-fired generation facility costs from rates by December 31, 2025. On December 19, 2024, the Washington Commission issued Order 01, requiring PSE to file revised tariff pages, with rates effective January 1, 2025, subject to refund pending final determination. The Washington Commission has set the matter for adjudication, with a hearing scheduled for September 3, 2025. The Washington Commission's order allows the rates to be collected beginning January 1, 2025, but explicitly notes this does not represent a resolution or final determination of any matter raised in Docket No. UE-240729.

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.

The following graduated scale used in the PCA mechanism resulted in the following Company and customer shares:


Puget Energy and
Puget Sound Energy	At June 30, 2025
(Dollars in Thousands)	Company's Share			Customers' Share			Total
Annual Power Cost Variability	Over	Under	Amount	Over	Under	Amount
(Over) and under collected up to $17 million	100%	100%	$17,000	—%	—%	$—	$17,000
(Over) and under collected between $17 - $40 million	35	50	11,500	65	50	11,500	23,000
(Over) or under collected beyond $40 million	10	10	7,476	90	90	67,286	74,762
Interest			—			1,218	1,218
Total (over) / under recovery			$35,976			$80,004	$115,980


Puget Energy and
Puget Sound Energy	At June 30, 2024
(Dollars in Thousands)	Company's Share			Customers' Share			Total
Annual Power Cost Variability	Over	Under	Amount	Over	Under	Amount
(Over) and under collected up to $17 million	100%	100%	$17,000	—%	—%	$—	$17,000
(Over) and under collected between $17 - $40 million	35	50	11,500	65	50	11,500	23,000
(Over) or under collected beyond $40 million	10	10	6,711	90	90	60,403	67,114
Interest			—			1,299	1,299
Total (over) / under recovery			$35,211			$73,202	$108,413

On April 30, 2025, PSE filed the 2024 PCA compliance report in Docket No. UE-250318. PSE proposed that the $3.1 million difference between the 2024 forecasted deferred balance of $98.2 million, which was set in rates from October 1, 2024, to December 31, 2025, and the actual 2024 deferred balance of $95.1 million be returned to the PCA tracking account for future disposition. Additionally, PSE requested to recover the forecasted 2025 deferred balance of $80.6 million from October 1, 2025 to December 31, 2026.

On April 30, 2024, PSE filed the 2023 PCA compliance report in Docket No. UE-240288. The Company proposed to pass back 2023 deferred balances from October 1, 2024 to December 31, 2025, resulting in credits to customers of $22.2 million. Additionally, PSE requested to recover the forecasted 2024 deferred balance of $98.2 million from October 1, 2024, to December 31, 2025. On September 26, 2024, the Washington Commission approved the filing as proposed with rates going into effect October 1, 2024 and January 1, 2025.

On July 8, 2025, PSE filed in Docket No. UE-250537 a tariff revision requesting that the Washington Commission eliminate the deadband and sharing bands in the PCA mechanism. The tariff revision is expected to be suspended and set for hearing.

Purchased Gas Adjustment Mechanism

On October 24, 2024, the Washington Commission approved PSE's request for PGA rates in Docket No. UG-240708, effective November 1, 2024. As part of that filing, PSE requested an annual overall revenue increase of $124.4 million, where PGA rates, under Schedule 101, decrease annual revenue by $2.6 million and the tracker rates, under Schedule 106, increase annual revenue by $127.0 million. The revenue increase in Schedule 106 is primarily due to the cessation of the counterparty refund of $28.1 million, mentioned above, that was amortized as a credit in 2023 and $142.8 million in commodity deferrals that were passed back to customers.

The following table presents the PGA mechanism balances and activity for the six months ended June 30, 2025 and the twelve months ended December 31, 2024:


Puget Energy and Puget Sound Energy
(Dollars in Thousands)	At June 30,		At December 31,
	2025		2024
PGA (liability)/receivable beginning balance	$	(58,657)	$	(132,082)
Actual natural gas costs	217,718		416,067
Allowed PGA recovery	(250,262)		(336,170)
Interest	(2,579)		(6,472)

PGA (liability)/receivable ending balance	$	(93,780)	$	(58,657)

For further information, such as prior rate filings and accounting petitions, see Part II, Item 8, Note 4, "Regulation and Rates" in the Company's Annual Report on Form 10-K for the year ended December 31, 2024.

(8) Commitments and Contingencies

Legal Matters

Washington Climate Commitment Act

In 2021, the Washington Legislature adopted the CCA, which establishes a GHG emissions cap-and-invest program that requires covered entities, including electric and natural gas utilities, to purchase allowances to cover their GHG emissions with a cap on available allowances beginning on January 1, 2023 that declines annually through 2050. The WDOE published final regulations to implement the program on September 29, 2022, which became effective on October 30, 2022. The WDOE also indicated that there will be subsequent rulemakings building off initial rulemaking as program implementation proceeds and Washington carbon goal progress is evaluated.

Compliance with the CCA requires covered entities to obtain allowances equal to their emissions and submit to the WDOE annually according to a staggered four-year compliance schedule. For the first three years of each compliance period, covered entities must submit allowances to cover at least 30% of their annual compliance obligation, as determined by the WDOE, no later than November 1st of the following year. For the fourth year of each compliance period, covered entities must submit sufficient allowances to cover 100% of their full four-year compliance obligation, as determined by the WDOE, no later than November 1st of the following year.

The WDOE provided an initial allocation of no-cost allowances to electric utilities, including PSE, for compliance years 2023, 2024 and 2025. However, qualifying electric utilities are allowed to submit revised emissions forecasts approved by the Washington Commission to WDOE. On July 10, 2025, the Washington Commission approved PSE's revised demand and resource supply forecast for calendar years 2025 and 2026, which revises PSE's electric emissions forecast and pending approval from the WDOE may affect the allocation of no-cost allowances provided by the WDOE for 2025. As of June 30, 2025, the Company's compliance obligation does not reflect the revised electric emissions forecast filed with the Washington Commission as it is pending approval, and, if approved, PSE plans to request a revised allocation of no-cost allowances from the WDOE for compliance year 2025.

On September 30, 2024, the WDOE provided notice to PSE that its 2023 annual compliance obligation was confirmed based on its 2023 reported covered emissions as previously reported to the WDOE. The WDOE has held subsequent meetings with electric utilities, including PSE, regarding CCA compliance issues related to the first compliance period. To date, WDOE has not made adjustments or “true up” accounting for allocation methods, forecasts or cost burden associated with the first compliance period for PSE. The WDOE has indicated that they will provide future guidance on how the adjustment (or “true-up”) mechanism will work going forward. Based on the determinations made by the WDOE in the aforementioned notices, PSE recorded a compliance obligation of $52.6 million for allowances for electric operations as of June 30, 2025. Given the

potential for future rulemakings and the WDOE's ability to adjust no-cost allowances during the compliance period, there is estimation uncertainty surrounding the Company's ability to estimate its compliance obligation both on an annual basis and a four-year compliance period, prior to a final WDOE determination.

As existing uncertainties are resolved in future periods, any change in compliance costs as a result of such estimated additional liabilities would be deferred under ASC 980 as a regulatory asset consistent with Docket No. UE-220974, as these amounts will be recoverable from customers in future utility rates. As a result, there is no current impact to the Company's consolidated statements of income.

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 entered into an agreement with NorthWestern Energy on July 30, 2024 to transfer PSE's ownership interest in Colstrip Units 3 and 4 to NorthWestern Energy on December 31, 2025. Management evaluated Colstrip Units 3 and 4 and determined that abandonment accounting criteria was met as of December 31, 2024. Thus, PSE will apply abandonment accounting on the transfer date of December 31, 2025. Until that date, Colstrip Units 3 and 4 are classified as electric utility plant on the Company's balance sheet as of June 30, 2025 and December 31, 2024.

For further information, see Part II, Item 8, Note 6, "Utility Plant" in the Company’s Annual Report on Form 10-K for the year ended December 31, 2024.

Other Commitments and Contingencies

In addition to the contractual obligations and consolidated commercial commitments disclosed in the Company's Annual Report on Form 10-K for the year ended December 31, 2024, during the six months ended June 30, 2025, the Company entered into new Electric Portfolio and Electric Wholesale Market Transaction contracts with estimated payment obligations totaling $146.1 million through 2054. For further information, see 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, 2024.

On July 22, 2025, the Company executed two agreements with the same counterparty that would provide the Company with the output of a 400 MW solar PV energy project and the capacity of a 200 MW battery energy storage system, both over a 25-year term. The total estimated payment obligation during the term of the agreements is approximately $2.1 billion. The agreements contain certain provisions that would allow the counterparty to terminate the agreements within 120 days of the execution date or if certain tax law changes occur for a nominal fee.

(9) Leases

PSE has operating leases for buildings for corporate offices and operations, real estate for operating facilities and the Tacoma LNG facility, land for wind farms, power tolling agreements and vehicles for PSE’s fleet. PSE has finance leases primarily for office buildings and office printers. The leases have remaining lease terms of less than a year to 44.2 years. PSE's ROU assets and lease liabilities include options to extend leases when it is reasonably certain that PSE will exercise that option.

On January 1, 2025, PSE commenced a tolling agreement to purchase the energy and capacity associated with a 650 MW natural gas combined cycle facility. The tolling agreement represents an operating lease to PSE and as of June 30, 2025, PSE recorded $171.8 million in right-of-use assets and $171.3 million in lease liabilities, included in the Company's consolidated balance sheets. The right-of-use asset is included in the operating lease right-of-use assets line item and liabilities are included in the operating lease liabilities line items under the current liabilities and other long-term and regulatory liabilities sections. Costs associated with the tolling agreement are included within purchased electricity on the Company's consolidated statements of income.

Leases Not Yet Commenced

On September 20, 2023, PSE entered into a tolling agreement to purchase the energy and capacity associated with a 132.5 MW facility. The tolling agreement represents a lease to PSE and is expected to commence in October 2025. PSE expects the total lease payment consideration to be $91.0 million over the five-year period beginning in October 2025.

On December 12, 2023, PSE entered into a lease for an operations training facility located in Puyallup, Washington. The lease is expected to commence in the third quarter of 2025 and PSE expects the total lease payment consideration to be $116.0 million over the 20-year term. Construction of the facility will be managed and contracted by the lessor, however, PSE will have involvement in the design of the facility.

On May 8, 2024, PSE entered into a battery energy storage services agreement that will be accounted for as a lease upon commencement. The lease is expected to commence in August 2027 and has a term of 20 years. The expected total lease payment consideration will approximate $744.0 million over the lease term.

On May 23, 2024, PSE entered into a battery energy storage services agreement that will be accounted for as a lease upon commencement. The lease is expected to commence in September 2027 and has a term of 25 years. The expected total lease payment consideration will approximate $856.2 million over the lease term.

On January 7, 2025, PSE entered into two battery energy storage services agreements that will be accounted for as leases upon commencement. These leases are expected to commence in January 2027 and each will have a term of 20 years. The expected total lease payment consideration will approximate $45.2 million over the lease terms.

(10) Other

Long-Term Debt

On March 13, 2025, Puget Energy issued $600.0 million of senior secured notes at an interest rate of 5.725%. The notes mature on March 15, 2035 and pay interest semi-annually in arrears on March 15 and September 15 of each year, commencing September 15, 2025. Proceeds from the issuance of the notes were used to repay Puget Energy's $400.0 million 3.65% senior secured notes that matured on May 15, 2025 and to pay down a portion of the outstanding balance on the Puget Energy senior secured credit facility and for general corporate purposes. A portion of the net proceeds were invested in short-term money market funds until they were used for their intended purposes.

On May 15, 2025, Puget Energy repaid at maturity the $400.0 million 3.65% senior secured notes due May 2025 and paid related expenses for a total cost of $407.3 million, which includes repayment of the $400.0 million principal and $7.3 million of accrued interest expense.

Liquidity Facilities and Other Financing Arrangements

As of June 30, 2025, $308.0 million was drawn and outstanding under Puget Energy's credit facility, which was classified as short-term debt on Puget Energy's consolidated balance sheet.

As of June 30, 2025, there was $55.0 million outstanding under the commercial paper program at PSE and no amount was drawn under PSE's credit facility. Outside of the credit facility, PSE maintains a standby letter of credit with TD Bank allowing for standby letter of credit postings of up to $150.0 million as a condition of transacting on the ICE NGX platform as well as participating in the Washington state carbon allowance auctions. As of June 30, 2025, $5.1 million was issued under a standby letter of credit with TD Bank in support of natural gas purchases and carbon allowance purchases. Additionally, PSE secured rights to $48.6 million of GHG emission allowances under the CCA, which did not clear until July 2, 2025 and thus was included in restricted cash, and had a $1.9 million letter of credit in support of a long-term transmission contract. In support of purchase power contracts, PSE posted no cash collateral and maintained three standby letters of credit in the amounts of $45.0 million, $13.5 million and $11.9 million.

In April 2025, Puget Energy borrowed $139.0 million on its credit facility and contributed the proceeds to PSE as an equity contribution. The equity proceeds were used for general corporate purposes.

For further information on the Company's long-term and short-term debt, credit facilities and other financing arrangements, 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, 2024.

Beaver Creek Wind Project

Beaver Creek is a utility-scale wind project located in Stillwater County, Montana, with an expected nameplate capacity of 248 MW that is expected to commence commercial operations in 2025. On September 15, 2023, PSE executed a membership interest purchase agreement with Caithness Beaver Creek, LLC for a 100% ownership interest in Caithness Montana Wind, LLC, which closed on December 1, 2023. Total consideration is expected to be $44.6 million of which $23.8 million has been paid as of June 30, 2025 and the remaining balance is expected to be paid in the third quarter of 2025. On December 1, 2023, PSE entered into a turbine supply agreement with GE Renewables North America, LLC to purchase 88 wind turbines. Total consideration is expected to be $266.9 million of which $260.3 million has been paid as of June 30, 2025 and the remaining balance is expected to be paid throughout the third quarter of 2025 as the project is completed. On January 26, 2024, PSE entered into a balance of plant agreement to complete the design and construction of the project. Total consideration is expected to be approximately $157.9 million. As of June 30, 2025, $561.7 million and $19.7 million was recorded to CWIP and ARO, respectively, in conjunction with the Beaver Creek wind project.

Appaloosa Solar Project

Appaloosa Solar Project is a utility-scale solar project located in Garfield County, Washington with an expected nameplate capacity of 142 MW that is expected to commence commercial operations in 2026. On December 22, 2023, PSE executed and closed a membership interest purchase agreement with HQC Solar Holdings 1, LLC for a 100% ownership interest in Appaloosa Solar Project LLC. Total consideration is expected to be $20.3 million, of which $18.6 million was paid as of June 30, 2025 and the remaining balance is expected to be paid in 2026. On August 30, 2024, PSE entered into an Engineering, Procurement, and Construction agreement to complete the design and construction of the project. Total consideration is expected to be approximately $266.8 million. As of June 30, 2025, $41.9 million was recorded to CWIP in conjunction with the project.

(11) Segment Information

Puget Energy operates one reportable segment referred to as the regulated utility segment (Regulated Utility), which is made up of its regulated subsidiary, PSE. No additional reportable segments are contained within PSE. The Regulated Utility segment generates, purchases and sells electricity and purchases, transports and sells natural gas. The service territory of PSE covers approximately 6,000 square miles in the state of Washington. Operations in addition to the Regulated Utility reportable segment, described as Other below, include the activities conducted at the holding company level and at Puget LNG, a non-regulated liquefied natural gas facility. The accounting policies of the Regulated Utility operating segment are the same as those described in Note 1, "Summary of Significant Accounting Policies" to the Combined Notes to Consolidated Financial Statements included in Item 1 of this report. The chief operating decision maker for both Puget Energy and PSE is the president and chief executive officer.

The chief operating decision maker uses net income for the Regulated Utility reportable segment to assess performance, determine resource allocation and gauge the Company's ability to attract and pursue capital investments by comparing actual results to budgeted amounts.

The following tables present financial information about the Regulated Utility segment and reconciliation to Puget Energy consolidated financial statements:


Puget Energy	Three Months Ended June 30, 2025						Six Months Ended June 30, 2025
(Dollars in Thousands)	Regulated Utility		Other		Total		Regulated Utility		Other		Total
Revenue	$	1,110,972	$	9,493	$	1,120,465	$	2,703,992	$	18,476	$	2,722,468
Depreciation and amortization	207,852		1,684		209,536		416,545		3,367		419,912
Income tax (benefit) expense	4,410		(5,345)		(935)		32,225		(12,662)		19,563
Non-utility expense and other	10,470		6,944		17,414		19,245		13,496		32,741
Interest expense	84,637		31,564		116,201		169,557		59,306		228,863
Net income	68,320		(24,146)		44,174		254,334		(42,604)		211,730
Total assets	17,310,818		1,925,503		19,236,321		17,310,818		1,925,503		19,236,321
Construction expenditures	(376,611)		(132)		(376,743)		(730,046)		(279)		(730,325)


Puget Energy	Three Months Ended June 30, 2024						Six Months Ended June 30, 2024
(Dollars in Thousands)	Regulated Utility		Other		Total		Regulated Utility		Other		Total
Revenue	$	987,434	$	6,534	$	993,968	$	2,533,871	$	14,514	$	2,548,385
Depreciation and amortization	193,814		1,652		195,466		384,006		3,336		387,342
Income tax (benefit) expense	2,112		(2,016)		96		22,330		(10,330)		12,000
Non-utility expense and other	7,046		4,451		11,497		10,193		12,247		22,440
Interest expense	76,768		30,068		106,836		153,381		55,903		209,284
Net income	(3,284)		(25,792)		(29,076)		144,615		(43,782)		100,833
Total assets	16,410,740		1,947,260		18,358,000		16,410,740		1,947,260		18,358,000
Construction expenditures	(341,544)		(135)		(341,679)		(716,606)		(377)		(716,983)

There are no significant segment expenses used by the chief operating decision maker to manage the segment’s operations that are not included in the Consolidated Statements of Income. PSE recognized revenue from Puget LNG for gas transportation services of $2.0 million and $1.0 million for the six months ended June 30, 2025 and 2024, respectively. These revenues are eliminated in Puget Energy's Consolidated Statements of Income. Puget LNG is charged tariff rates that are approved by the Washington Commission.

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis is intended to promote understanding of the results of operations and financial condition, is provided as a supplement to, and should be read in conjunction with the financial statements and related notes thereto included elsewhere in this report on Form 10-Q. This section generally discusses the results of operations and changes in financial condition for the period ended June 30, 2025 compared to 2024. For discussion related to the results of operations and changes in financial condition for the period ended June 30, 2024 compared to 2023 refer to Part I, Item 2, Management's Discussion and Analysis of Financial Condition and Results of Operations in our period ended June 30, 2024, Form 10-Q, which was filed with the United States Securities and Exchange commission (SEC). The discussion contains forward-looking statements that involve risks and uncertainties, such as Puget Energy, Inc. (Puget Energy) and Puget Sound Energy, Inc. (PSE) objectives, expectations and intentions. Words or phrases such as “anticipates,” “believes,” “continues,” “could,” “estimates,” “expects,” “future,” “intends,” “may,” “might,” “plans,” “potential,” “predicts,” “projects,” “should,” “will likely result,” “will continue” and similar expressions are intended to identify certain of these forward-looking statements. However, these words are not the exclusive means of identifying such statements. In addition, any statements that refer to expectations, projections or other characterizations of future events or circumstances are forward-looking statements. Readers are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date of this report. Puget Energy's and PSE's actual results could differ materially from results that may be anticipated by such forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those discussed in the section entitled “Forward-Looking Statements” included elsewhere in this report and in the section entitled "Risk Factors" included in Part I, Item 1A in Puget Energy's and PSE's Form 10-K for the period ended December 31, 2024. Except as required by law, neither Puget Energy nor PSE undertakes any obligation to revise any forward-looking statements in order to reflect events or circumstances that may subsequently arise. Readers are urged to carefully review and consider the various disclosures made in this report and in Puget Energy's and PSE's other reports filed with the SEC that attempt to advise interested parties of the risks and factors that may affect Puget Energy's and PSE's business, prospects and results of operations.

Overview

Puget Energy is an energy services holding company and substantially all of its operations are conducted through its wholly owned subsidiary PSE, a regulated electric and natural gas utility company. PSE is the largest electric and natural gas utility in the state of Washington, primarily engaged in the business of electric transmission, distribution and generation and natural gas distribution. Puget Energy's business strategy is to generate stable cash flows by offering reliable electric and natural gas service in a cost-effective manner through PSE. Puget Energy also has a wholly owned non-regulated subsidiary, Puget LNG, which has the sole purpose of owning and operating the non-regulated activity of the Tacoma liquefied natural gas (LNG) facility. Puget Holdings indirectly owns all of Puget Energy's common stock. Puget Holdings is owned by a consortium of long-term infrastructure investors including the British Columbia Investment Management Corporation (BCIMC), the Alberta Investment Management Corporation (AIMCo), the Ontario Municipal Employees Retirement System (OMERS), PGGM Vermogensbeheer B.V., Macquarie Washington Clean Energy Investment, L.P., and the Ontario Teachers’ Pension Plan Board. Puget Energy and PSE are collectively referred to herein as “the Company.”

PSE generates revenue and cash flow primarily from the sale of electric and natural gas services to residential and commercial customers within a service territory covering approximately 6,000 square miles, principally in the Puget Sound region of the state of Washington. PSE continually balances its load requirements, generation resources, purchase power agreements and market purchases to meet customer demand. The Company's external financing requirements principally reflect the cash needs of its construction program, its schedule of maturing debt and certain operational needs. PSE requires access to bank and capital markets to meet its financing needs.

Factors and Trends Affecting PSE's Performance

PSE’s ongoing regulatory requirements and operational needs necessitate the investment of substantial capital in 2025 and will continue to do so in future years. Because PSE intends to seek recovery of such investments through the regulatory process, its financial results depend heavily upon favorable outcomes from that process. The principal business, economic and other factors that affect PSE’s operations and financial performance include:

•The rates PSE is allowed to charge for its services;

•PSE’s ability to recover power costs that are subject to the Company's power cost adjustment mechanism that are included in rates, which are based on volume;

•Weather conditions, including the impact of temperature on customer load; the impact of extreme weather events on budgeted maintenance costs; meteorological conditions such as snow-pack, stream-flow and wind-speed which affect power generation, supply and price;

•The effects of climate change, including changes in the environment that may affect energy costs or consumption, increase the Company’s costs, or adversely affect its operations;

•Regulatory decisions allowing PSE to recover purchased power and fuel costs, on a timely basis;

•PSE’s ability to supply electricity and natural gas, through company-owned generation, purchase power contracts or by procuring natural gas or electricity in wholesale markets;

•Deferral of excess revenues if earnings exceed PSE's authorized rate of return (ROR) by more than 0.5%;

•Availability and access to capital and the cost of capital;

•Regulatory compliance costs, including those related to new and developing federal regulations of electric system reliability, state regulations of natural gas pipelines and federal, state and local environmental laws and regulations, such as the CCA;

•Wholesale commodity prices of electricity and natural gas;

•Increasing capital expenditures with additional depreciation and amortization;

•Failure to complete capital projects on schedule and within budget or the abandonment of capital projects, either of which could result in the Company’s inability to recover project costs or refund previously collected revenues;

•Changes in customer growth and customer usage;

•Tax reform, the effect of lower tax rates, and regulatory treatment of excess deferred tax balances on rate base and customer rates;

•General economic conditions, such as inflation, in PSE's operational territory and its effects on customer growth and use-per-customer;

•Federal, state, and local taxes;

•Employee workforce factors, including potential strikes, work stoppages, transitions in senior management, and loss or retirement of key personnel and availability of qualified personnel;

•The effectiveness of PSE’s risk management policies and procedures;

•Cybersecurity incidents, cybersecurity attacks, data security breaches or other malicious acts that cause damage to the Company’s generation and transmission facilities or information technology systems, or result in the release of confidential customer, employee, or Company information;

•Acts of war or terrorism locally or abroad, or the impact of civil unrest to infrastructure or preventing access to infrastructure and its impact on the supply chain and prices of goods and services;

•Natural disasters such as wildfires, earthquakes, hurricanes, floods, landslides and windstorms or the rise in frequency and magnitude of extreme temperature events; possible accidents, explosions, fires or mechanical breakdowns affecting or caused by PSE's facilities or infrastructure; changes in legislation, regulation and government policies including federal grant programs, trade restrictions and tariffs, and government staff reductions may increase the Company's costs, delay projects, interrupt service, impact PSE's generation, transmission and distribution systems, subject the Company to increased liability, and/or adversely affect its operations;

•Risks due to health crises, such as epidemics and pandemics, including supply shortages, rising costs, disruption to vendor or customer relationships, the potential for reputational harm, the impact of government, business and company closure of facilities, customer or contract defaults, concerns of safety to employees and customers, potential costs due to quarantining of employees and work-from-home policies, and the Company's and vendor staffing levels resulting from vaccination mandates; and

•Legislative, regulatory, code, and/or ordinance changes, including executive orders, tariffs and trade restrictions and budget and efficiency measures, including any actual or potential reduction in the federal workforce, that impact operations, electric and natural gas availability, sales, transmission, costs and/or delivery.

Regulation of PSE Rates and Recovery of PSE Costs

PSE's regulatory requirements, environmental compliance and operational needs require the investment of substantial capital in 2025 and future years. As PSE intends to seek recovery of these investments through the regulatory process, its financial results depend heavily upon outcomes from that process. The rates PSE is allowed to charge for its services influence its financial condition, results of operations and liquidity. PSE is highly regulated and the rates that it charges its retail customers are approved by the Washington Commission.

PSE’s mandate to pursue electric conservation initiatives may have a negative impact on the electric business financial performance due to lost margins from lower sales volumes as variable power costs are not part of the decoupling mechanism. Washington law and the Washington Commission also set natural gas conservation achievement standards for PSE. The effects of achieving these standards will, however, have only a minor negative impact on the natural gas business's financial performance due to the natural gas business being mostly decoupled.

In 2024, the Washington Governor signed the Washington Decarbonization Act for Large Combination Utilities, introduced as House Bill 1589, which requires PSE to file an integrated system plan that combines natural gas and electric planning into one process and include, among other objectives, planning scenarios that (i) achieve natural gas and electricity emissions reductions and costs associated therewith (including planning scenarios for a range of natural gas decarbonization and associated costs), (ii) achieve two percent of electric load annually with conservation and energy efficiency resources unless the Washington Commission finds that a higher target is cost effective, (iii) includes low-income electrification programs and (iv) include a 10-year clean energy action plan for implementing CETA at the lowest reasonable cost and at an acceptable resource adequacy standard and consolidation of multiple existing system plans into an integrated plan, which will be followed by three years of rulemaking and planning prior to the submission in 2027 of PSE’s first integrated system plan to the Washington Commission. The law also clarifies the application of certain regulatory mechanisms for PSE, including a Certificate of Necessity and usage of CWIP. For additional information on PSE's GRC filings, see Note 7, "Regulation and Rates" in the Combined Notes to Consolidated Financial Statements included in Item 1 of this report.

On March 29, 2024, senate bill 5950 approved Washington State's operating budget, which included $150.0 million for public and private utilities to provide one-time bill rebates for low-and moderate-income residential electric customers. PSE received a total of $45.9 million in 2024 and provided rebates to low-and moderate-income residential electric customers.

General Rate Case Filing

PSE filed a GRC which includes a two-year MYRP with the Washington Commission on February 15, 2024. On January 15, 2025, the Washington Commission issued an order on PSE's 2024 GRC, that approved a weighted cost of capital of 7.52% in 2025 and 7.64% in 2026, a capital structure of 49.0% in common equity in 2025 and 50.0% in 2026, and a return on equity of 9.8% in 2025 and 9.9% in 2026. On January 28, 2025, the Washington Commission approved PSE's electric and natural gas rates in its compliance filing with an overall net revenue change for electric of $378.2 million or 13.3% in 2025 and $191.0 million or 5.9% in 2026 and an overall net revenue change for natural gas of $110.0 million or 10.6% in 2025 and $20.0 million or 1.8% in 2026, with an effective date of January 29, 2025. PSE filed a petition for reconsideration on January 24, 2025 and multiple parties filed petitions for reconsideration and a motion for clarification on January 27, 2025. On March 17, 2025, the Washington Commission issued an order denying PSE’s petition for reconsideration. The order also granted certain petitions for reconsideration and clarification by other parties and denied certain petitions for reconsideration and clarification by other parties. The order approved PSE's Targeted Electrification Pilot Phase II.

For further information, such as prior rate filings, see Part II, Item 8, Note 4, "Regulation and Rates" in the Company's Annual Report on Form 10-K for the year ended December 31, 2024.

Electric Rates

The following table sets forth electric rate adjustments and the expected annual impact of PSE's revenue approved by the Washington Commission since the electric rate adjustments included in the Company's Annual Report included on Form 10-K for the year ended December 31, 2024 and inclusive of filings through the 10-K filing date of February 21, 2025. For further information on the rate schedule descriptions and prior approved filings, see Part I, Item 1, Business, "Regulation and Rates"

and Part II, Item 7, "Regulation of PSE Rates and Recovery of PSE Costs" respectively, in the Company's Annual Report on Form 10-K for the year ended December 31, 2024.


Electric	Schedule	Docket	Effective Date	Average Percentage Increase (Decrease) in Rates	Increase (Decrease) in Revenue (Dollars in Millions)
Conservation service rider	120	250123	May 1, 2025	1.2%	$37.7
Electric CCA supplemental	111E Supp1	250321	August 1, 2025	1.9	86.2
Low income program	129	250200	May 1, 2025	3.0	34.8
Property tax tracker	140	250207	May 1, 2025	0.3	10.3
Revenue decoupling adjustment mechanism	142	250203	May 1, 2025	(0.2)	(5.5)
Transportation electrification plan	141TEP	250197	May 1, 2025	0.1	4.6

_____________

1 Represents a rate increase from August 1, 2025 through December 31, 2026.

Natural Gas Rates

The following table sets forth natural gas rate adjustments and the expected annual impact of PSE's revenue approved by the Washington Commission since the natural gas rate adjustments included in the Company's Annual Report included on Form 10-K for the year ended December 31, 2024 and inclusive of filings through the 10-K filing date of February 21, 2025. For further information on the rate schedule descriptions and prior approved filings, see Part I, Item 1, Business, "Regulation and Rates" and Part II, Item 7, "Regulation of PSE Rates and Recovery of PSE Costs", respectively, in the Company's Annual Report on Form 10-K for the year ended December 31, 2024.


Natural gas	Schedule	Docket	Effective Date	Average Percentage Increase (Decrease) in Rates	Increase (Decrease) in Revenue (Dollars in Millions)
Conservation service rider	120	250124	May 1, 2025	0.5%	$5.7
Low income program	129	250201	May 1, 2025	3.1	7.8
Property tax tracker	140	250208	May 1, 2025	0.4	4.7
Revenue decoupling adjustment mechanism	142	250204	May 1, 2025	0.9	12.0

Access to Debt Capital

PSE relies on access to bank borrowings and short-term money markets as sources of liquidity and longer-term capital markets to fund its utility construction program, to meet maturing debt obligations and other capital expenditure requirements not satisfied by cash flow from its operations or equity investment from its parent, Puget Energy. Neither Puget Energy nor PSE have any outstanding debt whose maturity would accelerate upon a credit rating downgrade. However, a ratings downgrade could adversely affect the Company's ability to refinance existing or issue new long-term debt or obtain access to new or renew existing credit facilities, could increase the cost of issuing long-term debt and maintaining credit facilities, and could impact the Company's ability to pay dividends. For example, under Puget Energy's and PSE's credit facilities, the borrowing costs increase as their respective credit ratings decline due to increases in credit spreads and commitment fees. If PSE is unable to access debt capital on reasonable terms, its ability to pursue improvements or generating capacity acquisitions, which may be relied on for future growth and to otherwise implement its strategy, could be adversely affected. PSE monitors the credit environment and expects to continue to be able to access the capital markets to meet its short-term and long-term borrowing needs.

Regulatory Compliance Costs and Expenditures

PSE's operations are subject to extensive federal, state and local laws and regulations. These laws and regulations cover electric system reliability, natural gas pipeline system safety and energy market transparency, among other areas. Environmental laws and regulations related to air and water quality, climate change and endangered species protection, waste

handling and disposal (including generation by-products such as coal ash), remediation of contaminated sites and the environmental impacts of siting new facilities also impact the Company's operations. PSE must spend significant resources to fulfill requirements set by regulatory agencies, many of which have greatly expanded mandates on measures including resource planning, remediation, monitoring, pollution control equipment and emissions-related abatement and fees.

In 2021, the Washington Legislature adopted the CCA, which establishes a GHG emissions cap-and-invest program that requires covered entities to purchase allowances to cover their GHG emissions with a cap on available allowances beginning on January 1, 2023 that declines annually through 2050. The WDOE published final regulations to implement the program on September 29, 2022, effective October 30, 2022. The WDOE also indicated that it will have subsequent rulemakings building off initial rulemaking while program implementation is underway and progress with Washington carbon goals are evaluated.

As of July 24, 2025, the Washington Commission has approved the recovery of both electric and natural gas CCA-related costs, which increases costs to electric and natural gas customers. Further, the Washington Commission indicated these revenues are subject-to-refund, and thus, there is a risk PSE may not be able to recover all costs. PSE faces continued risks associated with the CCA, including the evolving nature of the CCA rulemaking and related interpretation of the rules, unresolved recovery methodology for the CCA’s impact on energy costs and risk sharing mechanisms, company costs, customer rate impacts, and cash, liquidity and credit volatility. For additional information, see Note 7, "Regulation and Rates" in the Combined Notes to Consolidated Financial Statements included in Item 1 of this report.

Compliance with these or other future regulations, such as those pertaining to climate change, could require significant capital expenditures by PSE and may adversely affect PSE's financial position, results of operations, cash flows and liquidity.

Other Challenges and Strategies

Competition

PSE’s electric and natural gas utility retail customers generally do not have the ability to choose their electric or natural gas supplier; therefore, PSE’s business has historically been recognized as a natural and regulated monopoly. However, PSE faces competition from public utility districts and municipalities or efforts by citizens organizing to form such entities that want to establish their own government-owned utility, as a result of which PSE may lose a number of customers. PSE's natural gas customers may also elect to use heating oil, propane or other fuels instead of purchasing and using natural gas. PSE also faces increasing competition for sales to its retail customers through alternative methods of electric energy generation, including solar and other self-generation methods.

Additionally, PSE faces increasing competition from other entities, primarily in the technology sector, where several large companies have entered into power purchase agreements to meet their growing energy needs, which will largely be used to fulfill commitments for additional cloud computing, artificial intelligence data centers, reduced carbon emissions and increased reliance on renewable energy sources. The increasing competitive pressure may impact the Company's ability to acquire generation and transmission resources and/or increase the cost to acquire such resources.

Results of Operations

Puget Sound Energy

The following discussion should be read in conjunction with the unaudited consolidated financial statements and the related notes included elsewhere in this document and provides significant items that impacted PSE’s results of operations for the three months and six months ended June 30, 2025 and June 30, 2024.

Non-GAAP Financial Measures - Electric and Natural Gas Margins

Financial information is prepared in accordance with GAAP, as well as two other financial measures, electric margin and natural gas margin, that are considered “non-GAAP financial measures.” Generally, a non-GAAP financial measure is a numerical measure of a company’s financial performance, financial position or cash flows that includes adjustments that result in a presentation that is not defined by GAAP. The presentation of electric margin and natural gas margin is intended to supplement an understanding of PSE’s operating performance. Electric margin and natural gas margin are used by PSE to determine whether PSE is collecting the appropriate amount of revenue from its customers in order to provide adequate recovery of operating costs, including interest and equity returns. PSE’s electric margin and natural gas margin measures may not be comparable to other companies’ electric margin and natural gas margin measures. Furthermore, these measures are not intended to replace operating income as determined in accordance with GAAP as an indicator of operating performance.

The following table presents operating income and a reconciliation of utility electric and natural gas margins to the most directly comparable GAAP measure, operating income:


Puget Sound Energy
(Dollars in Thousands)	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Operating income (loss)	$	125,438	$	50,552	$	386,792	$	271,981
Electric operating revenue	$	832,355	$	709,829	$	1,859,303	$	1,698,345
Purchased electricity	(276,118)		(255,849)		(657,646)		(641,614)
Electric generation fuel	(71,608)		(45,431)		(163,232)		(162,988)
Residential exchange	17,367		17,855		44,601		44,153
Electric margin (non-GAAP)	$	501,996	$	426,404	$	1,083,026	$	937,896
Natural gas operating revenue	$	271,283	$	277,524	$	837,256	$	835,344
Purchased natural gas	(97,484)		(133,180)		(343,999)		(404,533)
Natural gas margin (non-GAAP)	$	173,799	$	144,344	$	493,257	$	430,811
Other operating revenue	$	7,334	$	81	$	7,433	$	182
Unrealized gain (loss) on derivative instruments, net	—		(7,068)		—		(22,733)
Utility operation and maintenance	(207,957)		(192,665)		(440,342)		(395,782)
Non-utility expense and other	(10,470)		(7,046)		(19,245)		(10,193)
Depreciation and amortization	(244,159)		(223,471)		(500,732)		(451,495)
Taxes other than income taxes	(95,105)		(90,027)		(236,605)		(216,705)
Operating income (loss)	$	125,438	$	50,552	$	386,792	$	271,981

Electric Margin

Electric margin represents electric sales to retail and transportation customers less the cost of generating and purchasing electric energy sold to customers, including transmission costs, to bring electric energy to PSE's service territory.

The following chart displays the details of PSE's electric margin changes for the three months and six months ended June 30, 2025 and 2024:

______________

* Includes decoupling cash collections, ROR excess earnings, and decoupling 24-month revenue reserve.

Three Months Ended June 30, 2025 compared to 2024

Electric Operating Revenue

Electric operating revenues increased $122.5 million from the prior year primarily due to an increase in electric retail sales of $79.7 million, decoupling revenue of $15.0 million, sales to other utilities of $19.5 million and transportation and other revenue of $7.2 million. These items are discussed in detail below.

•Electric retail sales increased $79.7 million primarily from a rate increase resulting in an additional $96.6 million in sales compared to the prior year and partially offset by a decrease in retail electricity usage of 2.3% with an impact of $16.9 million. The increase in rates is primarily due to the tariffs filed pursuant to the Company's 2024 GRC. See "Regulation of PSE Rates and Recovery of PSE Costs" included in this Item 2 of this report and Part II, Item 7, Management's Discussion and Analysis, "Regulation of PSE Rates and Recovery of PSE Costs" included in the Company's Annual Report on Form 10-K for the year ended December 31, 2024 for electric rate changes. The decrease in retail usage was primarily due to a decrease in residential and industrial usage of 2.7% and 9.2%, respectively. The decrease in customer usage was driven by a decrease in heating degree days of 14.8% in the three months ended June 30, 2025 as compared to 2024.

•Sales to other utilities increased $19.5 million primarily due to a 36.6% increase in the average price of electric wholesale sales and a 22.9% increase in wholesale sales volume. Higher wholesale power prices were largely the result of elevated prices in June 2025 driven by lower Mid-Columbia hydro. Increased wholesale sales volume was related to increased supply, driven by additional generation facilities in 2025 compared to 2024.

•Decoupling revenue increased $15.0 million which was attributable to a $10.3 million and $4.7 million increases in delivery and fixed production cost deferral revenues, respectively. This was driven primarily by higher allowed rates in the three months ended June 30, 2025 compared to the same period in 2024.

•Transportation and other revenue increased $7.2 million primarily due to increased non-core gas sales, of which $3.6 million related to an increase in net wholesale non-core natural gas sales driven by an increase in both sales volumes and average price of sales, which outpaced the corresponding increase in the cost of non-core gas sold; and $3.8 million related to a decrease in financial hedging costs in 2025 compared to 2024.

Electric Power Costs

Electric power costs increased $46.9 million primarily due to an increase of electric generation fuel costs of $26.2 million and an increase in purchased electricity of $20.3 million. These items are discussed in detail below:

•Purchased electricity increased $20.3 million primarily due to wholesale electricity purchase volumes that increased by 14.9% in 2025 compared to 2024. This was partially offset by decreased wholesale purchase prices, which were 4.5% lower in 2025 compared to 2024.

•Electric generation fuel increased $26.2 million primarily driven by natural gas fuel costs related to a tolling agreement that commenced January 1, 2025 to purchase energy and capacity associated with a 650 MW natural gas-fired electric generating facility.

______________

* Includes decoupling cash collections, ROR excess earnings, and decoupling 24-month revenue reserve.

Six Months Ended June 30, 2025 compared to 2024

Electric Operating Revenue

Electric operating revenues increased $161.0 million from the prior year primarily due to an increase in electric retail sales of $187.0 million, decoupling revenue of $4.3 million, other decoupling revenue of $3.2 million; partially offset by decreases in sales to other utilities of $25.2 million. These items are discussed in detail below.

•Electric retail sales increased $187.0 million primarily from a rate increase resulting in an additional $176.6 million in sales compared to the prior year and partially offset by a slight increase in retail electricity usage of 0.6% with an impact of $10.5 million. The increase in rates is primarily due to the tariffs filed pursuant to the Company's 2024 GRC. See "Regulation of PSE Rates and Recovery of PSE Costs" included in this Item 2 of this report and Part II, Item 7, Management's Discussion and Analysis, "Regulation of PSE Rates and Recovery of PSE Costs" included in the Company's Annual Report on Form 10-K for the year ended December 31, 2024 for electric rate changes.

•Sales to other utilities decreased $25.2 million primarily due to a 18.3% decrease in the average price of electric wholesale sales partially offset by a slight increase in wholesale sales volume of 2.2%. Lower wholesale power prices were largely the result of lower natural gas prices in 2025 compared to 2024.

•Decoupling revenue decreased $4.3 million which was attributable to a $3.8 million and $0.5 million decrease in delivery and fixed production cost deferral revenues, respectively. This was driven primarily by higher usage in the six months ended June 30, 2025 compared to the same period in 2024.

•Other decoupling revenue increased $3.2 million primarily due to an increase in current period amortization of prior year decoupling revenues compared to the same period in 2024. This is attributable to an decrease in amortization rates, which increases the rate at which deferral revenues are passed back to customers.

Electric Power Costs

Electric power costs increased $15.8 million primarily due to an increase in purchased electricity of $16.0 million, which is discussed in detail below:

•Purchased electricity increased $16.0 million primarily due to wholesale electricity purchase volumes that increased by 17.9% in 2025 compared to 2024 which was partially offset by decreased wholesale purchase prices, which were 13.0% lower in 2025 compared to 2024.

Natural Gas Margin

Natural gas margin is natural gas sales to retail and transportation customers less the cost of natural gas purchased, including transportation costs to bring natural gas to PSE’s service territory. The PGA mechanism passes through increases or decreases in the natural gas supply portion of the natural gas service rates to customers based upon changes in the price of natural gas purchased from producers and wholesale marketers or changes in natural gas pipeline transportation costs. PSE's margin or net income is not affected by changes under the PGA mechanism because over- and under-recoveries of natural gas costs included in baseline PGA rates are deferred and either refunded to or collected from customers in future periods.

The following chart displays the details of PSE's natural gas margin changes for the three months and six months ended June 30, 2025 and 2024:

______________

* Includes decoupling cash collections, ROR excess earnings, and decoupling 24-month revenue reserve.

Three Months Ended June 30, 2025 compared to 2024

Natural Gas Operating Revenue

Natural gas operating revenue decreased $6.2 million primarily due to a decrease in transportation and other revenue of $27.7 million and other decoupling revenue of $2.9 million; which was partially offset by an increase in retail sales of $20.7 million and decoupling revenue of $3.7 million. These items are discussed in detail below.

•Natural gas retail sales revenue increased $20.7 million primarily due to an increase in rates of $61.6 million partially offset by a decrease in natural gas load of 13.9%, or $40.9 million. The increase in rates is primarily due to the tariffs filed pursuant to the Company's 2024 GRC effective January 29, 2025 and 2024 PGA filing effective November 1, 2024. This was partially offset by a decrease in rates driven by Schedule 111 that includes a charge for CCA allowance costs and a pass back of CCA auction proceeds. See Part II, Item 7, Management's Discussion and Analysis, "Regulation of PSE Rates and Recovery of PSE Costs" included in the Company's Annual Report on Form 10-K for the year ended December 31, 2024 for natural gas rate changes. The decrease in natural gas load was driven by a decrease in heating degree days of 14.8% in the three months ended June 30, 2025 as compared to 2024.

•Decoupling revenue increased $3.7 million primarily due to lower natural gas usage, as mentioned above, in 2025 compared to 2024.

•Other decoupling revenue decreased $2.9 million primarily due to an increase in current period amortization of prior year decoupling revenues compared to the same period in 2024. This is attributable to an increase in amortization rates, which increases the rate at which deferral revenues are collected from customers.

•Transportation and other revenue decreased $27.7 million due to a decrease of $41.4 million related to the regulatory offset of CCA auction proceeds passed back to customers, which were passed through to customers as credits on billed revenue included within natural gas retail revenues above. The decrease was partially offset by $12.8 million related to the Company’s deferred return on its investment in the Tacoma LNG Facility and an increase of $3.3 million related to the regulatory offset of bill discounts under Schedule 129D, which are passed back to customers as credits on billed revenue included within natural gas retail revenues above.

Natural Gas Energy Costs

•Purchased natural gas expense decreased $35.7 million primarily due to a decrease of $47.1 million in amortization of deferred CCA emission allowance costs, which were passed through to customers as billed revenue included within natural gas retail revenues above and a decrease in natural gas usage of 13.9% as stated in the natural gas retail sales section above. This was partially offset by an increase in the PGA rates in November 2024. For natural gas rate changes and details on the PGA, see Management's Discussion and Analysis, "Regulation of PSE Rates and Recovery of PSE Costs" included in Part II, Item 7 of the Company's Annual Report on Form 10-K for the year ended December 31, 2024.

______________

* Includes decoupling cash collections, ROR excess earnings, and decoupling 24-month revenue reserve.

Six Months Ended June 30, 2025 compared to 2024

Natural Gas Operating Revenue

Natural gas operating revenue increased $1.9 million primarily due to an increase in retail sales of $135.6 million, which was partially offset by decreases in transportation and other revenue of $95.5 million, decoupling revenue of $23.3 million and other decoupling revenue of $14.8 million. These items are discussed in detail below.

•Natural gas retail sales revenue increased $135.6 million primarily due to an increase in rates of $143.3 million partially offset by a decrease in natural gas load of 1.0%, or $7.7 million. The increase in rates is primarily due to the tariffs filed pursuant to the Company's 2024 GRC effective January 29, 2025 and 2024 PGA filing effective November 1, 2024. This was partially offset by a decrease in rates driven by Schedule 111 that includes a charge for CCA allowance costs and a pass back of CCA auction proceeds. See Part II, Item 7, Management's Discussion and Analysis, "Regulation of PSE Rates and Recovery of PSE Costs" included in the Company's Annual Report on Form 10-K for the year ended December 31, 2024 for natural gas rate changes.

•Decoupling revenue decreased $23.3 million primarily due to higher delivery rates in 2025 compared to 2024.

•Other decoupling revenue decreased $14.8 million primarily due to an increase in current period amortization of prior year decoupling revenues compared to the same period in 2024. This is attributable to an increase in amortization rates, which increases the rate at which deferral revenues are collected from customers.

•Transportation and other revenue decreased $95.5 million due to a decrease of $111.2 million related to the regulatory offset of CCA auction proceeds passed back to customers, which were passed through to customers as credits on billed revenue included within natural gas retail revenues above. The decreases were partially offset by an increase of $10.0 million related to the regulatory offset of bill discounts under Schedule 129D, which are passed back to customers as credits on billed revenue included within natural gas retail revenues above and $7.7 million related to the Company’s deferred return on its investment in the Tacoma LNG Facility.

Natural Gas Energy Costs

•Purchased natural gas expense decreased $60.5 million primarily due to a decrease of $129.3 million in amortization of deferred CCA emission allowance costs, which were passed through to customers as billed revenue included within natural gas retail revenues above and a decrease in natural gas usage of 1.0% as stated in the natural gas retail sales section above. This was partially offset by an increase in the PGA rates in November 2024. For natural gas rate changes and details on the PGA, see Management's Discussion and Analysis, "Regulation of PSE Rates and Recovery of PSE Costs" included in Part II, Item 7 of the Company's Annual Report on Form 10-K for the year ended December 31, 2024.

Other Operating Expenses and Other Income (Deductions)

The following chart displays the details of PSE's operating expenses and other income (deductions) for the three months and six months ended June 30, 2025 and 2024:

Three Months Ended June 30, 2025 compared to 2024

•Net unrealized (gain) loss on derivative instruments decreased $7.1 million due to the Washington Commission's approval of the Company's accounting petition in Docket No. UE-240773 to offset any derivative assets or liabilities, entered into in order to serve electric customers, with a regulatory asset or liability, thus deferring the unrealized gains or losses. For additional information, see Note 4, "Accounting for Derivative Instruments and Hedging Activities" and Note 7, "Regulation and Rates" in Item 1 of this report.

•Utility operations and maintenance expense increased $15.3 million primarily due to increases in the following: (i) $12.2 million related to customer service expense, driven by an increase in Schedule 129 - low income program in electric and natural gas rates, see Management's Discussion and Analysis, "Regulation of PSE Rates and Recovery of PSE Costs" included in Part II, Item 7 of the Company's Annual Report on Form 10-K for the year ended December 31, 2024, (ii) $5.2 million of miscellaneous general expenses driven by increases to call center, training and other customer records and collection expenses, as well as outside services, (iii) $2.8 million related to insurance expense driven by wildfire insurance, (iv) $2.1 million related to plant maintenance and (v) $2.1 million related to leak surveys, locates and inspections. The increases were partially offset by $11.4 million in deferred O&M costs related to approved trackers that are being recovered through rates.

•Non-utility expense and other increased $3.5 million primarily due to $5.9 million of costs associated with a sale of land at PSE's wholly-owned subsidiary, Puget Western Inc. in May 2025.

•Depreciation and amortization expense increased $20.7 million due to increases in the following: (i) $6.7 million increase in conservation amortization due to increases in conservation rates effective May 1, 2025, see "Regulation of PSE Rates and Recovery of PSE Costs" included in this Item 2 of this report, (ii) $8.7 million increase in electric production and electric general plant depreciation primarily driven by net additions to the Upper Baker Dam and waterway and advanced distribution management system computer software assets, respectively and (iii) $6.0 million

increase in electric transmission and distribution plant primarily driven by net additions of transmission poles and underground conductors, respectively.

•Taxes other than income taxes increased $5.1 million primarily due to an increase of $3.9 million in state excise taxes in 2025 as compared to 2024.

Other Income, Interest Expense and Income Tax Expense

•Other income/expense increased $5.0 million from net other income of $16.0 million in 2024 to net other income of $21.0 million in 2025, due to an increase of $11.9 million in other income that was partially offset by an increase of $6.9 million in other expense. The increase in other income was primarily due to an increase of $6.7 million related to advanced metering infrastructure interest income and a $5.4 million increase in equity AFUDC due to an increase in eligible CWIP and AFUDC rates. The increase in other expense was primarily due to an increase of $3.3 million related to Colstrip major maintenance.

•Interest expense increased $5.9 million primarily due to an increase of $8.6 million in interest expense due to the June 2024 PSE bond issuances. This was partially offset by an increase in AFUDC debt of $1.9 million in 2025 and a decrease in other common interest expense of $1.5 million due to less short-term commercial paper borrowing in 2025 as compared to 2024.

•Income tax expense increased $2.3 million primarily driven by an increase in pre-tax book income in 2025 as compared to 2024.

Six Months Ended June 30, 2025 compared to 2024

•Net unrealized (gain) loss on derivative instruments decreased $22.7 million due to the Washington Commission's approval of the Company's accounting petition in Docket No. UE-240773 to offset any derivative assets or liabilities, entered into in order to serve electric customers, with a regulatory asset or liability, thus deferring the unrealized gains or losses. For additional information, see Note 4, "Accounting for Derivative Instruments and Hedging Activities" and Note 7, "Regulation and Rates" in Item 1 of this report.

•Utility operations and maintenance expense increased $44.6 million primarily due to increases in the following: (i) $28.6 million related to customer service expense, driven by an increase in Schedule 129 - low income program in electric and natural gas rates, see Management's Discussion and Analysis, "Regulation of PSE Rates and Recovery of PSE Costs" included in Part II, Item 7 of the Company's Annual Report on Form 10-K for the year ended December 31, 2024, (ii) $4.6 million related to insurance expense driven by wildfire insurance, (iii) $4.1 million of miscellaneous general expenses driven by increases to call center, training and other customer records and collection expenses and (iv) $3.0 million related to leak surveys, locates and inspections. The increases were partially offset by $4.2 million in deferred O&M costs related to approved trackers that are being recovered through rates.

•Non-utility expense and other increased $9.0 million primarily due to $5.9 million of costs associated with a sale of land at PSE's wholly-owned subsidiary, Puget Western Inc. in May 2025 and an increase in the long-term incentive plan of $5.7 million in 2025 as compared to 2024.

•Depreciation and amortization expense increased $49.2 million due to increases in the following: (i) $16.7 million increase in conservation amortization due to increases in conservation rates effective May 1, 2025, see "Regulation of PSE Rates and Recovery of PSE Costs" included in this Item 2 of this report, (ii) $17.3 million increase in electric production and electric general plant depreciation primarily driven by net additions to the Upper Baker Dam and waterway and advanced distribution management system computer software assets, respectively, (iii) $11.8 million increase in electric transmission and distribution plant primarily driven by net additions of transmission poles and underground conductors, respectively and (iv) $3.6 million increase in natural gas distribution primarily driven by net additions of plastic mains assets.

•Taxes other than income taxes increased $19.9 million primarily due to an increase of $16.2 million in state excise taxes and an increase of $11.7 million in municipal taxes; partially offset by a $5.7 million decrease in property taxes.

Other Income, Interest Expense and Income Tax Expense

•Other income/expense increased $18.0 million from net other income of $30.3 million in 2024 to net other income of $48.3 million in 2025, due to an increase of $26.4 million in other income that was partially offset by an increase of $8.3 million in other expense. The increase in other income was primarily due to a $12.3 million increase in equity AFUDC due to an increase in eligible CWIP and AFUDC rates and an increase of $11.5 million related to advanced metering infrastructure interest income. The increase in other expense was primarily due to an increase of $3.3 million related to Colstrip major maintenance.

•Interest expense increased $13.2 million primarily due to an increase of $19.6 million in interest expense due to the June 2024 PSE bond issuances. This was partially offset by a decrease in other common interest expense of $4.9 million due to less short-term commercial paper borrowing in 2025 as compared to 2024.

•Income tax expense increased $9.9 million primarily driven by an increase in pre-tax book income in 2025 as compared to 2024.

Puget Energy

Primarily, all operations of Puget Energy are conducted through PSE. Puget Energy's net income (loss) for the three months and six months ended June 30, 2025 and 2024 is as follows:

Three Months Ended June 30, 2025 compared to 2024

Summary Results of Operation

Puget Energy’s net income increased by $73.3 million. This is primarily due to: (i) an increase in PSE's net income of $71.6 million, (ii) an increase in other operating revenue and income of $2.3 million driven by short-term interest earned from re-investing proceeds of Puget Energy's $600.0 million bond issued in early March 2025 and (iii) increased tax benefit of $3.4 million. The increases were partially offset by an increase in interest expense of $2.2 million, which was driven by interest expense accrued for Puget Energy's $600.0 million bond issuance in early March 2025.

Six Months Ended June 30, 2025 compared to 2024

Summary Results of Operation

Puget Energy’s net income increased by $110.9 million. This is primarily due to: (i) an increase in PSE's net income of $109.7 million, (ii) an increase in other operating revenue and income of $4.0 million driven by short-term interest earned from re-investing proceeds of Puget Energy's $600.0 million bond issued in early March 2025 and (iii) increased tax benefit of $2.5 million. The increases were partially offset by an increase in interest expense of $4.8 million, which was driven by interest expense accrued for Puget Energy's $600.0 million bond issuance in early March 2025.

Capital Requirements

Contractual Obligations and Commercial Commitments

Off-Balance Sheet Arrangements

As of June 30, 2025, the Company had no off-balance sheet arrangements that have had or are reasonably likely to have a material effect on the Company's financial condition. The Company does have standby letter of credit arrangements. For more information, see Note 10, "Other" in the Combined Notes to Consolidated Financial Statements included in Item 1 of this report.

Utility Construction Program

The Company’s construction programs for generating facilities, the electric transmission system, the natural gas and electric distribution systems and the Tacoma LNG facility are designed to meet regulatory requirements, support customer

growth and improve energy system reliability. The Company adjusted capital expenditures, resulting in a decrease of $189.3 million compared to forecasted amounts for the six months ended June 30, 2025. The decrease was primarily due to timing and project scheduling resulting in underspending in (i) generation projects, (ii) information technology projects, and (iii) decarbonization projects. Construction expenditures, excluding equity AFUDC, totaled $730.3 million for the six months ended June 30, 2025. Presently planned utility construction expenditures, excluding equity AFUDC, are as follows:


Capital Expenditure Projections
(Dollars in Millions)	2025	2026	2027
Total energy delivery, technology and facilities expenditures	$1,676.1	$1,789.6	$2,421.1

The program is subject to change based upon general business, economic and regulatory conditions. Utility construction expenditures and any new generation resource expenditures may be funded from a combination of sources, which may include cash from operations, short-term debt, long-term debt and/or equity. PSE’s planned capital expenditures may result in a level of spending that will exceed its cash flow from operations. As a result, execution of PSE’s strategy is dependent in part on continued access to capital markets.

Capital Resources

Cash from Operations


Puget Sound Energy	Six Months Ended June 30,
(Dollars in Thousands)	2025		2024		Change
Net income	$	254,334	$	144,615	$	109,719
Non-cash items1	496,886		442,278		54,608
Changes in cash flow resulting from working capital2	(65,503)		19,000		(84,503)

Regulatory assets and liabilities	(37,628)		8,593		(46,221)
Purchased gas adjustment	35,123		(50,722)		85,845
GHG emission allowances	(90,587)		(60,565)		(30,022)
Other non-current assets and liabilities3	10,200		(2,066)		12,266
Net cash provided by operating activities	$	602,825	$	501,133	$	101,692

_______________

1 Non-cash items include depreciation, amortization, deferred income taxes, net unrealized (gain) loss on derivative instruments, AFUDC-equity, PTCs and other miscellaneous non-cash items.

2 Changes in working capital include receivables, unbilled revenue, materials/supplies, fuel/gas inventory, income taxes, prepayment, accounts payable and accrued expenses.

3 Other non-current assets and liabilities include funding of pension liability.

Six Months Ended June 30, 2025 compared to 2024

Cash generated from operations for the six months ended June 30, 2025 increased by $101.7 million, which includes a net income increase of $109.7 million. The following are significant factors that impacted PSE's cash flows from operations:

•Cash flows resulting from non-cash items increased $54.6 million primarily due to: (i) an increase in deferred taxes of $29.4 million, (ii) an increase in depreciation and amortization of $32.5 million, (iii) an increase of $16.7 million in conservation amortization, (iv) an increase of $7.9 million related to the deferral of energy exchange costs, and (v) an increase of $5.4 million related to the amortization of regulatory filing fees. The increases were partially offset by: (i) a $22.7 million change in net unrealized loss on derivative instruments due to the deferral of unrealized gain or loss on derivative instruments consistent with the approved accounting petition in Docket No. UE-240773, (ii) a change in equity AFUDC of $12.3 million and (iii) a decrease of $3.7 million related to the amortization of deferred return on PSE's share of the Tacoma LNG investment.

•Cash flows resulting from changes in working capital decreased $84.5 million primarily due to: (i) accounts payable decreased faster in 2025 compared to 2024, which led to increased cash outflow of $28.0 million, (ii) cash outflow of $30.3 million due to the timing of accounts receivable collections, as the balance of accounts receivable decreased $112.8 million in 2025 compared to a decrease of $143.0 million in 2024 and (iii) cash outflow of $17.0 million in material and supplies due to purchase of network devices and system equipment for the Advanced Metering

Infrastructure network, (iv) cash outflow of $9.5 million in prepayments, primarily driven by higher prepayments for purchased electricity, (v) cash outflow of $3.3 million related to lower transmission services deposits received and (vi) cash outflow of $3.2 million related to annual filing fees paid to the Washington Commission. The decreases were partially offset by cash inflow of $8.2 million due to a decrease in fuel inventory in 2025 compared to 2024.

•Cash flows resulting from regulatory assets and liabilities decreased $46.2 million primarily due to: (i) $10.7 million cash outflow in the PCA due to actual power costs being higher than baseline rates in both periods, but to a larger degree in 2025 compared to 2024, (ii) $19.8 million cash outflow related to the Bill Discount Rate Rider as actual discounts provided were lower than amounts collected through the rate in 2024, whereas in 2025 actual discounts provided were higher than amounts collect through the rate, (iii) $13.4 million cash outflow from incremental deferrals of bad debt expense related to COVID-19 in 2025 compared to 2024, and (iv) $3.7 million of cash outflow driven by higher expenses incurred for conservation in 2025 compared to 2024.

•Cash flows resulting from purchased gas adjustment increased $85.8 million, which was primarily driven by a $68.9 million increase in allowed PGA recovery in 2025 compared to 2024 and a $16.9 million decrease in actual natural gas cost.

•Cash flow resulting from GHG emission allowances decreased $30.0 million due to purchases made to obtain the Washington emission allowances for GHG emissions associated with the Company's electric and natural gas business activities in compliance with the CCA.

•Other non-current assets and liabilities increased $12.3 million, which is primarily driven by higher schedule 129 -low income program rates in the first six months of 2025 compared to 2024.


Puget Energy	Six Months Ended June 30,
(Dollars in Thousands)	2025		2024		Change
Net income	$	(42,604)	$	(43,782)	$	1,178
Non-cash items1	8,693		19,976		(11,283)
Changes in cash flow resulting from working capital2	9,532		1,939		7,593



Other non-current assets and liabilities3	(2,137)		(1,331)		(806)
Net cash provided by operating activities	$	(26,516)	$	(23,198)	$	(3,318)

_______________

1 Non-cash items include depreciation, amortization, deferred income taxes, net unrealized (gain) loss on derivative instruments, AFUDC-equity, PTCs and other miscellaneous non-cash items.

2 Changes in working capital include receivables, unbilled revenue, materials/supplies, fuel/gas inventory, income taxes, prepayments, accounts payable and accrued expenses.

3 Other noncurrent assets and liabilities include funding of pension liability.

Six Months Ended June 30, 2025 compared to 2024

Cash generated from operations for the six months ended June 30, 2025, in addition to the changes discussed at PSE above, decreased by $3.3 million compared to the same period in 2024, which includes a net income increase of $1.2 million.

•Changes in cash flow resulting from non-cash items decreased $11.3 million primarily due to a $13.3 million change in deferred taxes.

•Changes in cash flow resulting from working capital increased $7.6 million primarily due to increased accrued interest, primarily driven by the $600.0 million 5.725% senior secured notes issued in March 2025. The increase was partially offset by a reduction in interest related to the maturity of the $400.0 million 3.65% senior secured notes, which matured in May 2025.

Financing Program

The Company’s external financing requirements principally reflect the cash needs of its construction program, its schedule of maturing debt and certain operational needs. The Company anticipates refinancing the redemption of bonds or other long-term borrowings with its credit facilities and/or the issuance of new long-term debt. Access to funds depends upon factors such as Puget Energy’s and PSE’s credit ratings, prevailing interest rates and investor receptivity to investing in the utility industry, Puget Energy and PSE. The Company believes it has sufficient liquidity through its credit facilities and access to capital markets to fund its needs over the next twelve months.

Proceeds from PSE’s short-term borrowings and sales of commercial paper are used to provide working capital and the interim funding of utility construction programs. Puget Energy and PSE continue to have reasonable access to the capital and credit markets.

In the second quarter of 2025, Moody's, S&P and Fitch issued annual rating agency reports and affirmed both Puget Energy (Baa3/BBB-/BBB-) and PSE (Baa1/BBB/BBB+) credit ratings and retained stable outlooks from all three agencies. Thus, as of June 30, 2025, both Puget Energy and PSE have stable outlooks from Moody’s, S&P and Fitch. Although neither Puget Energy nor PSE have any outstanding debt whose maturity would be accelerated upon a ratings downgrade, Management continually monitors the credit rating environment for both Puget Energy and PSE as a credit rating downgrade may increase the cost of borrowing for Puget Energy and PSE in future long-term financings or under their existing credit facilities. Any increase in the cost of borrowing could negatively impact Puget Energy and PSE's future results of operations as well as future liquidity, access to debt capital resources and financial condition. Additionally, a ratings downgrade could impact the Company's ability to issue dividends. A downgrade to Puget Energy and PSE's credit ratings would not impact debt covenants under our existing credit facilities nor would it impact other contracts, as neither include credit rating triggering event clauses. A credit rating decrease for PSE could result in increased cash collateral required for commodity contracts, which would adversely affect PSE's liquidity. Management cannot predict with certainty the actions credit agencies may take, if any, in response to weaker near term credit metrics, regulatory and rate recovery uncertainties, and management's efforts to contain the growth of capital and operating expenditures. Containing the growth of capital and operating expenditures will be limited, over the near term, due to continuing strategic and risk mitigation imperatives and the necessity of providing safe, reliable and resilient service levels to customers.

Puget Sound Energy

Debt Restrictive Covenants

The type and amount of future long-term financings for PSE may be limited by provisions in PSE's electric and natural gas mortgage indentures.

PSE’s ability to issue additional secured debt may also be limited by certain restrictions contained in its electric and natural gas mortgage indentures. Under the most restrictive tests at June 30, 2025, PSE could issue:

•Approximately $0.9 billion of additional first mortgage bonds under PSE’s electric mortgage indenture based on approximately $1.5 billion of electric bondable property available for issuance, subject to an interest coverage ratio limitation of 2.0 times net earnings available for interest (as defined in the electric utility mortgage), which PSE exceeded at June 30, 2025; and

•Approximately $1.2 billion of additional first mortgage bonds under PSE’s natural gas mortgage indenture based on approximately $1.9 billion of natural gas bondable property available for issuance, subject to a combined natural gas and electric interest coverage test of 1.75 times net earnings available for interest and a natural gas interest coverage test of 2.0 times net earnings available for interest (as defined in the natural gas utility mortgage), both of which PSE exceeded at June 30, 2025.

At June 30, 2025, PSE had approximately $9.9 billion in electric and natural gas rate base to support the interest coverage ratio limitation test for net earnings available for interest.

Dividend Payment Restrictions

The payment of dividends by PSE to Puget Energy is restricted by provisions of certain covenants applicable to long-term debt contained in PSE’s electric and natural gas mortgage indentures. At June 30, 2025, approximately $2.1 billion of unrestricted retained earnings was available for the payment of dividends under the most restrictive mortgage indenture covenant.

Pursuant to the terms of the Washington Commission merger order, PSE may not declare or pay dividends if PSE’s common equity ratio, calculated on a regulatory basis, is 44.0% or below except to the extent a lower equity ratio is ordered by the Washington Commission. Also, pursuant to the merger order, PSE may not declare or make any distribution unless on the date of distribution PSE’s corporate credit/issuer rating is investment grade, or, if its credit ratings are below investment grade, PSE’s ratio of earnings before interest, tax, depreciation and amortization (EBITDA) to interest expense for the most recently ended four fiscal quarter periods prior to such date is equal to or greater than 3.0 to 1.0. The common equity ratio, calculated on a regulatory basis, was 49.7% at June 30, 2025, and the EBITDA to interest expense ratio was 4.9 to 1.0 for the twelve months ended June 30, 2025.

PSE’s ability to pay dividends is also limited by the terms of its credit facilities, pursuant to which PSE is not permitted to pay dividends during any Event of Default (as defined in the facilities), or if the payment of dividends would result in an Event of Default, such as failure to comply with certain financial covenants.

At June 30, 2025, the Company was in compliance with all applicable covenants, including those pertaining to the payment of dividends.

For more information on PSE's credit facilities, long term debt, demand promissory note, and shelf registrations see Part I, Item 1, Note 10, "Other" of this report and 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, 2024.

Puget Energy

Dividend Payment Restrictions

Puget Energy’s ability to pay dividends is also limited by the merger order issued by the Washington Commission in 2009. Pursuant to the merger order, Puget Energy may not declare or make a distribution unless on such date Puget Energy’s ratio of consolidated EBITDA to consolidated interest expense for the four most recently ended fiscal quarters prior to such date is equal to or greater than 2.0 to 1.0. Puget Energy's EBITDA to interest expense was 3.6 to 1.0 for the twelve months ended June 30, 2025.

At June 30, 2025, the Company was in compliance with all applicable covenants, including those pertaining to the payment of dividends.

For further information on Puget Energy's credit facilities, shelf registrations, and long-term debt, see Part I, Item 1, Note 10, "Other" included in this report and 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, 2024.

Other

New Accounting Pronouncements

For the discussion of new accounting pronouncements, see Note 2, "New Accounting Pronouncements" in the Combined Notes to Consolidated Financial Statements included in Item 1 of this report.

One Big Beautiful Bill Act

On July 4th, 2025, the One Big Beautiful Bill Act (OBBB) was signed into law. The OBBB includes a range of tax reforms and modifications to certain provisions included in the Tax Cuts and Jobs Act of 2017. The OBBB also impacts certain provisions included in the Inflation Reduction Act of 2022 by modifying or accelerating various tax incentives. While the OBBB does not have a material impact on the Company's financial statements for the period ended June 30, 2025, the Company is in the process of evaluating its potential for future impacts.

Washington Clean Energy Transformation Act

In 2019, Washington passed the CETA, which supports Washington's clean energy economy and transitioning to a clean, affordable, and reliable energy future. The CETA requires all electric utilities to (i) eliminate coal-fired generation from their in-state electric supply to customers by December 31, 2025; (ii) be carbon-neutral by January 1, 2030 through a combination of non-emitting electric generation, renewable generation, and/or alternative compliance options; and (iii) makes it the state policy that, by 2045, 100% of electric generation and retail electricity sales will come from renewable or non-emitting resources. Clean Energy Implementation Plans (CEIP) are required every four years from each IOU. The plan must propose interim targets for meeting the 2045 standard between 2030 and 2045 and describe an actionable plan that the IOU intends to pursue to meet the standard. The Washington Commission may approve, reject or recommend alterations to an IOU’s plan. The Company intends to seek recovery of any costs associated with CETA through the regulatory process. On December 17, 2021, PSE filed its final CEIP, which proposed a plan for the implementation of CETA for 2022-2025 and associated project costs. On June 6, 2023, the Washington Commission approved PSE’s CEIP, subject to conditions. On November 2, 2023, PSE filed a Biennial CEIP Update with the Commission.

Washington Climate Commitment Act

In 2021, the Washington Legislature adopted the CCA, which establishes a GHG emissions cap-and-invest program that requires covered entities, including electric and gas utilities, to purchase allowances to cover their GHG emissions with a cap on available allowances beginning on January 1, 2023, then declining annually through 2050. The WDOE published final regulations on September 29, 2022, which became effective on October 30, 2022. Allowances can be obtained through quarterly auctions, or bought and sold on a secondary market.

As an electric utility, PSE is required to obtain emission allowances or offset credits for GHG emissions associated with (i) electricity generated in Washington (ii) electricity imported into the state to serve Washington load, and (iii) all PSE facilities with total annual emissions exceeding 25,000 metric tons of carbon dioxide equivalent per year. As an electric utility subject to

Washington’s CETA, which is discussed below, PSE receives emission allowances from WDOE at no cost through 2050 for direct emissions associated with electricity used to serve Washington State load to eliminate the cost burden of the program on electric ratepayers.

As a natural gas utility, PSE is required to obtain emission allowances for GHG emissions associated with (i) natural gas supplied to customers and (ii) any natural gas system associated facilities with emissions that exceed 25,000 metric tons of carbon dioxide equivalent per year. PSE receives some no-cost emission allowances from WDOE to mitigate impacts to natural gas ratepayers. WDOE's allocation of no-cost allowances to PSE is based on a percentage of PSE baseline natural gas system related emissions (determined from 2015-2019 natural gas system related emissions) and declines annually in accordance with the requirements of the CCA.

Offset credit use is limited and is not additive to allowances; the WDOE subtracts any offsets used from the total allowance budget. In the first compliance period, 2023-2026, participating entities can cover up to 5% of their emissions with offset credits, and can cover an additional 3% with credits from projects on federally recognized Tribal lands. In the second compliance period, 2027-2030, the general limit drops to 4%, with an additional 2% from projects on Tribal lands.

In 2023, the WDOE announced an intent to pursue an agreement with California and Quebec to link with their cap and trade programs.

Integrated Resource Plans, Resource Acquisition and Development

For further information, see Part I, Item 1 “Integrated Resource Plans, Resource Acquisition and Development” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2024.

Environmental Remediation

The Company is subject to federal and state requirements for protection of the environment, including those for the discharge of hazardous materials and remediation of contaminated sites. A potentially responsible party has joint and several liability under existing U.S. environmental laws. In instances where we have been designated a potentially responsible party by the Environmental Protection Agency or state environmental agency, we are potentially liable for the cost of remediating contamination at existing and former work sites. Such sites include former manufactured gas plants and contaminated facilities operated by PSE predecessors, such as Gas Works Park on the shore of Lake Union in Seattle and a long-defunct creosote manufacturer, which had purchased waste products from PSE predecessors (e.g. Quendall Terminals site on Lake Washington in Renton, Washington), respectively. In each case, PSE assesses the environmental remediation obligations related to the contaminated sites based on in-depth studies, which include assessments of the probabilities of recovery from other responsible parties and/or insurance carriers, expert analyses and legal reviews. PSE develops a range of reasonably estimable costs that includes a low and high end of a range for all remediation sites for which we have sufficient information. There are some potential remediation obligations where the costs of remediation cannot be reasonably estimated. Liabilities are recorded based on the best estimate or the low end of a range of reasonably possible costs expected to be incurred to remediate sites. It is possible that costs are incurred in excess of the recorded amounts because of changes in laws and/or regulations, the solvency of other liable parties, higher than expected costs and/or the discovery of new or additional contamination. The Company believes a significant portion of its past and future environmental remediation costs are recoverable from insurance companies, third parties and/or customers under a Washington Commission order.

For additional information see Part II, Item 8, Note 4, "Regulation and Rates" in the Company’s Annual Report on Form 10-K for the year ended December 31, 2024.

Grid Resilience and Innovation Partnerships Program

In 2021, the Infrastructure Investment and Jobs Act was signed into law, which among other investments and programs, established the U.S. Department of Energy’s (DOE) Grid Resilience and Innovation Partnerships (GRIP) Program. The GRIP program was established to enhance grid flexibility and improve the resilience of the power system against growing threats of extreme weather and climate change. PSE has been selected for three grant awards under the GRIP program either through individual applications or participating in consortium grant applications: (i) PSE participated in the North Plains Connector grant consortium along with other utilities in the Pacific Northwest region that on August 7, 2024 was selected for a grant of $700.0 million of federal cost sharing; (ii) PSE applied for the Skagit River Valley Transformation for Climate Resiliency project that was selected on October 18, 2024 for a grant of $45.8 million of federal cost sharing; and (iii) PSE partnered in a coalition with E Source and other Pacific Northwest utilities on the Increasing Energy Resilience via Technology Investment Acceleration project, which was selected on October 18, 2024 for a grant of $77.0 million of federal cost sharing. As of the time of this report, all three grants must complete award negotiations and proceed to a signed award with the DOE in order to receive federal cost sharing funds and, pursuant to recently signed executive orders, the federal government's activities with

respect to such awards has been temporarily paused. Thus, at this time, the Company cannot predict the timing or amount of federal cost sharing that may be received.

Item 3. Quantitative and Qualitative Disclosure about Market Risk

The Company is exposed to various forms of market risk, consisting primarily of adverse changes in commodity prices, counterparty credit risk, as well as interest rate risk. PSE actively manages market risk and maintains risk policies and procedures designed to discourage unauthorized risk-taking, reduce commodity price volatility, and manage the various risks inherent to the energy portfolio. There have been no material changes to market risks affecting the Company from those set forth in Part II, Item 7A - "Quantitative and Qualitative Disclosures about Market Risk" in the Company’s Annual Report on Form 10-K for the year ended December 31, 2024.

Commodity Price Risk

The nature of serving regulated electric and natural gas customers with its portfolio of owned and contracted electric generation resources exposes PSE and its customers to some volumetric and commodity price risks. PSE’s Energy Risk Management Committee establishes energy risk management policies and procedures to manage commodity and volatility risks and the related effects on credit, tax, accounting, financing and liquidity.

PSE's objective is to minimize commodity price exposure and risks associated with volumetric variability in the natural gas and electric portfolios. It is not engaged in the business of assuming risk for the purpose of speculative trading. PSE hedges open natural gas and electric positions to reduce both the portfolio risk and the volatility risk in prices.

Counterparty Credit Risk

PSE is exposed to credit risk primarily through buying and selling electricity and natural gas to serve customers. Credit risk is the potential loss resulting from a counterparty's non-performance under an agreement. PSE manages credit risk with policies and procedures for counterparty analysis and measurement, monitoring and mitigation of exposure. Additionally, PSE has entered into commodity master arrangements (i.e., WSPP, ISDA or NAESB) with its counterparties to mitigate credit exposure.

Interest Rate Risk

The Company believes its interest rate risk primarily relates to the use of short-term debt instruments, variable-rate leases, and anticipated long-term debt financing needed to fund capital requirements. 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 and borrowings under its commercial paper program and its credit facilities to meet short-term funding needs. During periods of financial market or interest rate volatility, the Company may utilize its credit facilities for short term funding needs instead of the commercial paper program. Credit facility borrowings are based on a more stable base rate and the credit spread is fixed. Short-term obligations are commonly refinanced with fixed-rate bonds or notes when needed and when interest rates are considered favorable. The Company may also enter into swaps or other financial hedge instruments to manage the interest rate risk associated with the debt.

Item 4. Controls and Procedures

Puget Energy

Evaluation of Disclosure Controls and Procedures

Under the supervision and with the participation of Puget Energy’s management, including the President and Chief Executive Officer and the Senior Vice President and Chief Financial Officer, Puget Energy has evaluated the effectiveness of its disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934) as of June 30, 2025, the end of the period covered by this report. Based upon that evaluation, the President and Chief Executive Officer and the Senior Vice President and Chief Financial Officer of Puget Energy concluded that these disclosure controls and procedures are effective.

Changes in Internal Control over Financial Reporting

There have been no changes in Puget Energy’s internal control over financial reporting during the quarter ended June 30, 2025 that have materially affected, or are reasonably likely to materially affect, Puget Energy’s internal control over financial reporting.

Puget Sound Energy

Evaluation of Disclosure Controls and Procedures

Under the supervision and with the participation of PSE’s management, including the President and Chief Executive Officer and the Senior Vice President and Chief Financial Officer, PSE has evaluated the effectiveness of its disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934) as of June 30, 2025, the end of the period covered by this report. Based upon that evaluation, the President and Chief Executive Officer and the Senior Vice President and Chief Financial Officer of PSE concluded that these disclosure controls and procedures are effective.

Changes in Internal Control over Financial Reporting

There have been no changes in PSE’s internal control over financial reporting during the quarter ended June 30, 2025 that have materially affected, or are reasonably likely to materially affect, PSE’s internal control over financial reporting.

PART II OTHER INFORMATION

Item 1. Legal Proceedings

Contingencies arising out of the Company's normal course of business existed as of June 30, 2025. Litigation is subject to numerous uncertainties and the Company is unable to predict the ultimate outcome of these matters. For further details, see Note 8, "Commitments and Contingencies" in the Combined Notes to Consolidated Financial Statements included in Item 1 of this report.

SEC regulations require the Company to disclose certain information about proceedings arising under federal, state or local environmental provisions if the Company reasonably believes that such proceedings may result in monetary sanctions above a stated threshold. Pursuant to the SEC regulations and given the size of the Company's operations, the Company elected a threshold of $1.0 million for purposes of determining whether disclosure of any such proceedings is required. As of the date of this filing, we are not aware of any matters that exceed this threshold and meet the definition for disclosure.

Item 1A. Risk Factors

There have been no material changes from the risk factors set forth in Part I, Item 1A, "Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2024.


	3(i).1	Amended Articles of Incorporation of Puget Energy, Inc. (incorporated herein by reference to Exhibit 3.1 to Puget Energy’s Current Report on Form 8-K, dated February 6, 2009, Commission File No. 1-16305).
	3(i).2	Amended and Restated Articles of Incorporation of Puget Sound Energy, Inc. (incorporated herein by reference to Exhibit 3.2 to Puget Sound Energy's Current Report on Form 8-K, dated February 6, 2009, Commission File No. 1-4393).
	3(ii).1	Amended and Restated Bylaws of Puget Energy, Inc., as amended by the First Amendment to the Amended and Restated Bylaws of Puget Energy, Inc., dated January 6, 2022 (incorporated herein by reference to Exhibit 3.3 to Puget Energy's Annual Report on Form 10-K, dated February 25, 2022, Commission File No. 001-16305).
	3(ii).2	Amended and Restated Bylaws of Puget Sound Energy, Inc., as amended by the First Amendment to the Amended and Restated Bylaws of Puget Sound Energy, Inc., dated January 6, 2022 (incorporated herein by reference to Exhibit 3.4 to Puget Sound Energy's Annual Report on Form 10-K dated February 25, 2022, Commission File No. 001-04393).
*	22.1	Issuers of Guaranteed Securities and Affiliates Whose Securities Collateralize Securities of the Registrant.
*	31.1	Chief Executive Officer certification of Puget Energy pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*	31.2	Chief Financial Officer certification of Puget Energy pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*	31.3	Chief Executive Officer certification of Puget Sound Energy pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*	31.4	Chief Financial Officer certification of Puget Sound Energy pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*	32.1	Chief Executive Officer certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*	32.2	Chief Financial Officer certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
	101	Financial statements from the Quarterly Report on Form 10-Q of Puget Energy, Inc. and Puget Sound Energy, Inc. for the quarter ended June 30, 2025 filed on July 30, 2025 formatted in Inline XBRL: (i) the Consolidated Statement of Income (Unaudited), (ii) the Consolidated Statements of Comprehensive Income (Unaudited), (iii) the Consolidated Balance Sheets (Unaudited), (iv) the Consolidated Statements of Cash Flows (Unaudited), (v) the Consolidated Statements of Common Shareholder's Equity (Unaudited), and (vi) the Notes to Consolidated Financial Statements
	104	Cover Page Interactive Data File (embedded within the Inline XBRL document).


		PUGET ENERGY, INC. PUGET SOUND ENERGY, INC.
		/s/ Stacy Smith
		Stacy Smith Controller & Principal Accounting Officer
Date:	July 30, 2025


		Page
Definitions		3
Filing Format		3
Forward-Looking Statements		4

Part I.	Financial Information	5

Item 1.	Financial Statements	5
	Puget Energy, Inc.
	Consolidated Statements of Income – Three and Si x Months Ended June 30, 2025 and 2024	5
	Consolidated Statements of Comprehensive Income – Three and Six Months Ended June 30 , 2025 and 2024	6
	Consolidated Balance Sheets – June 30 , 2025 and December 31, 2024	7
	Consolidated Statements of Common Shareholder's Equity - June 30 , 2025 and December 31, 2024	8
	Consolidated Statements of Cash Flows – Six Months Ended June 30 , 2025 and 2024	9

	Puget Sound Energy, Inc.
	Consolidated Statements of Income – Three and Si x Months Ended June 30, 2025 and 2024	12
	Consolidated Statements of Comprehensive Income – Three and Six Months Ended June 30 , 2025 and 2024	11
	Consolidated Balance Sheets – June 30 , 2025 and December 31, 2024	12
	Consolidated Statements of Common Shareholder's Equity - June 30, 2025 and December 31, 2024	14
	Consolidated Statements of Cash Flows – Six Months Ended June 30, 2025 and 2024	15

	Notes
	Combined Notes to Consolidated Financial Statements	16

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	36

Item 3.	Quantitative and Qualitative Disclosure About Market Risk	58

Item 4.	Controls and Procedures	58

Part II.	Other Information	59

Item 1.	Legal Proceedings	59

Item 1A.	Risk Factors	59

Item 5.	Other Information	59

Item 6.	Exhibits	59

Exhibit Index		60

Signatures		61


	Common Stock			Additional Paid-in Capital				Accumulated Other Comprehensive Income (Loss)
	Shares	Amount				Retained Earnings				Total Equity













Balance at December 31, 2023	200	$	—	$	3,523,532	$	1,419,311	$	17,539	$	4,960,382
Net income (loss)	—	—		—		129,909		—		129,909
Common stock dividend paid	—	—		—		(84,050)		—		(84,050)
Other comprehensive income (loss)	—	—		—		—		(2,399)		(2,399)
Balance at March 31, 2024	200	$	—	$	3,523,532	$	1,465,170	$	15,140	$	5,003,842
Net income (loss)	—	—		—		(29,076)		—		(29,076)
Common stock dividend paid	—	—		—		(56,891)		—		(56,891)
Capital contribution	—	—		292,800		—		—		292,800
Other comprehensive income (loss)	—	—		—		—		(553)		(553)
Balance at June 30, 2024	200	$	—	$	3,816,332	$	1,379,203	$	14,587	$	5,210,122
Balance at December 31, 2024	200	$	—	$	3,816,332	$	1,508,705	$	43,168	$	5,368,205
Net income (loss)	—	—		—		167,556		—		167,556
Common stock dividend paid	—	—		—		(19,979)		—		(19,979)
Other comprehensive income (loss)	—	—		—		—		(1,014)		(1,014)
Balance at March 31, 2025	200	$	—	$	3,816,332	$	1,656,282	$	42,154	$	5,514,768
Net income (loss)	—	—		—		44,174		—		44,174
Common stock dividend paid	—	—		—		(3,395)		—		(3,395)

Other comprehensive income (loss)	—	—		—		—		(1,012)		(1,012)
Balance at June 30, 2025	200	$	—	$	3,816,332	$	1,697,061	$	41,142	$	5,554,535