XCEL ENERGY INC (Form: 8-K, Received: 02/05/2026 06:01:53)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of

the Securities Exchange Act of 1934

Date of Report (Date of earliest event reported) February 5, 2026


Commission File Number	Exact Name of Registrant as Specified in its Charter; State of Incorporation; Address of Principal Executive Offices; and Telephone Number				IRS Employer Identification Number
001-3034	XCEL ENERGY INC.				41-0448030
	(a Minnesota corporation)
	414 Nicollet Mall
	Minneapolis,	Minnesota		55401
	(612)		330-5500

000-31387	NORTHERN STATES POWER COMPANY				41-1967505
	(a Minnesota corporation)
	414 Nicollet Mall
	Minneapolis,	Minnesota		55401
	(612)		330-5500

001-03140	NORTHERN STATES POWER COMPANY				39-0508315
	(a Wisconsin corporation)
	1414 W. Hamilton Avenue
	Eau Claire,	Wisconsin		54701
	(715)		737-2625

001-3280	PUBLIC SERVICE COMPANY OF COLORADO				84-0296600
	(a Colorado corporation)
	3500 Blake Street
	Denver,	Colorado		80205
	(303)		571-7511

001-03789	SOUTHWESTERN PUBLIC SERVICE COMPANY				75-0575400
	(a New Mexico corporation)
	790 South Buchanan
	Amarillo,	Texas		79101
	(303)		571-7511

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):

☐ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

☐ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

☐ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

☐ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (17 CFR §230.405) or Rule 12b-2 of the Securities Exchange Act of 1934 (17 CFR §240.12b-2).

Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Securities registered pursuant to Section 12(b) of the Act:

Title of each class

Trading Symbol

Name of each exchange on which registered

Common Stock

XEL

Nasdaq Stock Market LLC

6.25% Junior Subordinated Notes due 2085

XELLL

Nasdaq Stock Market LLC

Item 2.02. Results of Operations and Financial Condition

On February 5, 2026, Xcel Energy released earnings results for the fourth quarter of 2025.

See additional information in the Earnings Release furnished as exhibit 99.01.

Item 9.01. Financial Statements and Exhibits

(d) Exhibits


Exhibit No.						Description

99.01						Earnings Release of Xcel Energy dated Fe b. 5 , 202 6 .

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.


Feb. 5, 2026			Xcel Energy Inc. (a Minnesota corporation)
			Northern States Power Company (a Minnesota corporation)
			Northern States Power Company (a Wisconsin corporation)
			Public Service Company of Colorado (a Colorado corporation)
			Southwestern Public Service Company (a New Mexico corporation)

			/s/ BRIAN J. VAN ABEL
			Brian J. Van Abel
			Executive Vice President, Chief Financial Officer

Exhibit 99.01


			414 Nicollet Mall
Feb. 5, 2026			Minneapolis, MN 55401

XCEL ENERGY

2025 YEAR END EARNINGS REPORT

•2025 GAAP diluted earnings per share were $3.42 compared with $3.44 per share in 2024.

•2025 diluted ongoing earnings per share were $3.80 compared with $3.50 per share in 2024.

•Xcel Energy reaffirms 2026 EPS guidance of $4.04 to $4.16 per share.

MINNEAPOLIS — Xcel Energy Inc. (NASDAQ: XEL) today reported 2025 GAAP diluted earnings of $2.02 billion, or $3.42 per share, compared with $1.94 billion, or $3.44 per share in the same period in 2024 and ongoing earnings of $2.24 billion, or $3.80 per share, compared with $1.97 billion, or $3.50 per share in the same period in 2024. See Note 6 for reconciliation from GAAP to ongoing earnings.

The change in ongoing earnings reflect increased recovery of infrastructure investments and electric sales growth, partially offset by higher interest, depreciation and operating & maintenance expenses.

“In 2025, Xcel Energy delivered on our earnings guidance for the 21st year in a row - one of the best track records in the industry. We placed in service critical infrastructure to serve our customers, including Phase 2 of our Sherco Solar facility, the conversion of our Harrington coal plant to natural gas, and the first two segments of our Colorado Power Pathway. All the while, our customers continue to have some of the lowest energy bills in the country,” said Bob Frenzel, chairman, president and CEO of Xcel Energy.

“As we look forward into 2026, we recently announced another large data center customer. We also announced two strategic alliances with industry-leading development and supply chain partners to help ensure we have the right resources to deliver critical system investments affordably, accelerate data center development for the benefit of all of our customers, and drive innovation. We are excited for the future and to make energy work better for our customers and communities.”

At 9:00 a.m. CDT today, Xcel Energy will host a conference call to review financial results. To participate in the call, please dial in 5 to 10 minutes prior to the start and follow the operator’s instructions.


US Dial-In:			1-800-715-9871
International Dial-In:			1-646-307-1963
Conference ID:			5265704

The conference call also will be simultaneously broadcast and archived on Xcel Energy’s website at www.xcelenergy.com. To access the presentation, click on Investors under Company. If you are unable to participate in the live event, the call will be available for replay for one week following the event.


Replay Numbers
US Dial-In:			1-800-770-2030

Access Code:			5265704

Except for the historical statements contained in this report, the matters discussed herein are forward-looking statements that are subject to certain risks, uncertainties and assumptions. Such forward-looking statements, including those relating to 2026 EPS guidance, long-term EPS and dividend growth rate objectives, future sales, future expenses, future tax rates, future operating performance, estimated base capital expenditures and financing plans, projected capital additions and forecasted annual revenue requirements with respect to rider filings, expected rate increases or refunds to customers, expectations and intentions regarding regulatory proceedings, expected pension contributions, and expected impact on our results of operations, financial condition and cash flows of interest rate changes, increased credit exposure, and legal proceeding outcomes, as well as assumptions and other statements are intended to be identified in this document by the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “objective,” “outlook,” “plan,” “project,” “possible,” “potential,” “should,” “will,” “would” and similar expressions. Actual results may vary materially. Forward-looking statements speak only as of the date they are made, and we expressly disclaim any obligation to update any forward-looking information. The following factors, in addition to those discussed in Xcel Energy’s Annual Report on Form 10-K for the fiscal year ended Dec. 31, 2024 and subsequent filings with the Securities and Exchange Commission, could cause actual results to differ materially from management expectations as suggested by such forward-looking information: operational safety, including our nuclear generation facilities and other utility operations; successful long-term operational planning; physical and financial risks associated with wildfires; commodity risks associated with energy markets and production; rising energy prices and fuel costs; qualified employee workforce and third-party contractor factors; violations of our Codes of Conduct; our ability to recover costs and our subsidiaries’ ability to recover costs from customers; changes in regulation; reductions in our credit ratings and the cost of maintaining certain contractual relationships; general economic conditions, including recessionary conditions, inflation rates, monetary fluctuations, supply chain constraints and their impact on capital expenditures and/or the ability of Xcel Energy Inc. and its subsidiaries to obtain financing on favorable terms; availability or cost of capital; our customers’ and counterparties’ ability to pay their debts to us; assumptions and costs relating to funding our employee benefit plans and health care benefits; our subsidiaries’ ability to make dividend payments; tax laws; uncertainty regarding epidemics; effects of geopolitical events, including war and acts of terrorism; cybersecurity threats and data security breaches; seasonal weather patterns; changes in environmental laws and regulations; climate change and other weather events; natural disaster and resource depletion, including compliance with any accompanying legislative and regulatory changes; costs of potential regulatory penalties and wildfire damages in excess of liability insurance coverage; regulatory changes and/or limitations related to the use of natural gas as an energy source; challenging labor market conditions and our ability to attract and retain a qualified workforce; and our ability to execute on our strategies or achieve expectations related to environmental, social and governance matters including as a result of evolving legal, regulatory and other standards, processes, and assumptions, the pace of scientific and technological developments, increased costs, the availability of requisite financing, and changes in carbon markets.

For more information, contact:




Roopesh Aggarwal, Vice President - Investor Relations			(612) 215-4535

Xcel Energy website address: www.xcelenergy.com			(612) 215-5300

This information is not given in connection with any

sale, offer for sale or offer to buy any security.

XCEL ENERGY INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

(amounts in millions, except per share data)


	Three Months Ended Dec. 31				Twelve Months Ended Dec. 31
	2025		2024		2025		2024
Operating revenues
Electric	$	2,809	$	2,410	$	12,160	$	11,147
Natural gas	737		695		2,452		2,230
Other	15		15		57		64
Total operating revenues	3,561		3,120		14,669		13,441

Operating expenses
Electric fuel and purchased power	925		925		3,961		3,788
Cost of natural gas sold and transported	333		287		1,041		951
Cost of sales — other	3		2		11		14
Operating and maintenance expenses	679		618		2,732		2,540
Conservation and demand side management expenses	107		99		406		394
Depreciation and amortization	753		702		2,953		2,744
Taxes (other than income taxes)	172		140		686		624
Marshall Wildfire litigation	9		—		296		—


Total operating expenses	2,981		2,773		12,086		11,055

Operating income	580		347		2,583		2,386

Other income, net	114		68		235		143
Earnings from equity method investments	20		—		17		19
Allowance for funds used during construction — equity	85		49		281		168

Interest charges and financing costs
Interest charges — includes other financing costs	403		319		1,468		1,255
Allowance for funds used during construction — debt	(39)		(22)		(125)		(73)
Total interest charges and financing costs	364		297		1,343		1,182

Income before income taxes	435		167		1,773		1,534
Income tax benefit	(132)		(297)		(245)		(402)
Net income	$	567	$	464	$	2,018	$	1,936

Weighted average common shares outstanding:
Basic	595		575		587		563
Diluted	597		576		589		563

Earnings per average common share:
Basic	$	0.95	$	0.81	$	3.44	$	3.44
Diluted	0.95		0.81		3.42		3.44

XCEL ENERGY INC. AND SUBSIDIARIES

Notes to Investor Relations Earnings Release (Unaudited)

Due to the seasonality of Xcel Energy’s operating results, quarterly financial results are not an appropriate base from which to project annual results.

Non-GAAP Financial Measures

The following discussion includes financial information prepared in accordance with generally accepted accounting principles (GAAP), as well as certain non-GAAP financial measures such as ongoing return on equity (ROE), ongoing earnings and ongoing diluted EPS. Generally, a non-GAAP financial measure is a measure of a company’s financial performance, financial position or cash flows that adjusts measures calculated and presented in accordance with GAAP. Xcel Energy’s management uses non-GAAP measures for financial planning and analysis, for reporting of results to the Board of Directors, in determining performance-based compensation and communicating its earnings outlook to analysts and investors. Non-GAAP financial measures are intended to supplement investors’ understanding of our performance and should not be considered alternatives for financial measures presented in accordance with GAAP. These measures are discussed in more detail below and may not be comparable to other companies’ similarly titled non-GAAP financial measures.

Ongoing ROE

Ongoing ROE is calculated by dividing the net income or loss of Xcel Energy or each subsidiary, adjusted for certain

nonrecurring items, by each entity’s average stockholder’s equity. We use these non-GAAP financial measures to evaluate and provide details of earnings results.

Earnings Adjusted for Certain Items (Ongoing Earnings and Ongoing Diluted EPS)

GAAP diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock (i.e., common stock equivalents) were settled. The weighted average number of potentially dilutive shares outstanding used to calculate Xcel Energy Inc.’s diluted EPS is calculated using the treasury stock method. Ongoing earnings reflect adjustments to GAAP earnings (net income) for certain items. Ongoing diluted EPS for Xcel Energy is calculated by dividing net income or loss, adjusted for certain items, by the weighted average fully diluted Xcel Energy Inc. common shares outstanding for the period. Ongoing diluted EPS for each subsidiary is calculated by dividing the net income or loss for such subsidiary, adjusted for certain items, by the weighted average fully diluted Xcel Energy Inc. common shares outstanding for the period.

We use these non-GAAP financial measures to evaluate and provide details of Xcel Energy’s core earnings and underlying performance. For instance, to present ongoing earnings and ongoing diluted earnings per share, we may adjust the related GAAP amounts for certain items that are non-recurring in nature. We believe these measurements are useful to investors to evaluate the actual and projected financial performance and contribution of our subsidiaries. These non-GAAP financial measures should not be considered as an alternative to measures calculated and reported in accordance with GAAP.

Note 1. Earnings Per Share Summary

Xcel Energy’s 2025 GAAP diluted earnings were $3.42 per share compared to $3.44 per share in 2024 and ongoing diluted earnings were $3.80 per share in 2025, compared with $3.50 per share in 2024. The change in ongoing earnings per share was driven by increased recovery of infrastructure investments and electric sales growth, partially offset by higher interest, depreciation and O&M expenses. Fluctuations in electric and natural gas revenues associated with changes in fuel and purchased power and/or natural gas sold and transported generally do not significantly impact earnings (changes in costs are offset by the related variation in revenues). See Note 6 for reconciliation of GAAP earnings to ongoing earnings.

Summarized diluted EPS for Xcel Energy:


	Three Months Ended Dec. 31				Twelve Months Ended Dec. 31
Diluted Earnings (Loss) Per Share	2025		2024		2025		2024
NSP-Minnesota	$	0.36	$	0.35	$	1.53	$	1.41
PSCo	0.36		0.33		1.15		1.39
SPS	0.13		0.12		0.67		0.70
NSP-Wisconsin	0.08		0.05		0.27		0.24
Earnings from equity method investments — WYCO	0.01		0.01		0.03		0.03
Regulated utility (a)	0.94		0.85		3.65		3.76
Xcel Energy Inc. and Other	0.01		(0.05)		(0.23)		(0.33)
GAAP diluted EPS (a)	$	0.95	$	0.81	$	3.42	$	3.44
Sherco Unit 3 2011 outage refunds (b)	—		—		—		0.06
Marshall Wildfire settlement (b)	0.01		—		0.38		—
Ongoing diluted EPS (a)	$	0.96	$	0.81	$	3.80	$	3.50

(a)Amounts may not add due to rounding.

(b)See Note 6.

NSP-Minnesota — GAAP earnings increased $0.12 per share and ongoing earnings increased $0.06 per share for 2025 compared to 2024. Ongoing earnings increased due to higher recovery of electric infrastructure investments, partially offset by increased O&M expenses, depreciation and interest charges. See Note 6 for reconciliation from GAAP to ongoing earnings.

PSCo — GAAP earnings decreased $0.24 per share and ongoing earnings increased $0.14 per share for 2025 (difference in GAAP and ongoing due to Marshall Wildfire settlement in 2025, see Note 6 for reconciliation from GAAP to ongoing earnings). Ongoing earnings increased due to higher recovery of electric and natural gas infrastructure investments and increased AFUDC, which was partially offset by increased depreciation, interest and O&M charges.

SPS — GAAP and ongoing earnings decreased $0.03 per share for 2025. The decrease was driven by increased interest charges, O&M expenses and the negative impact of weather, partially offset by sales growth and higher recovery of electric infrastructure investments.

NSP-Wisconsin — GAAP and ongoing earnings increased $0.03 per share for 2025. The increase was driven by higher recovery of electric and natural gas infrastructure investments, which was partially offset by increased depreciation and O&M expenses.

Xcel Energy Inc. and Other — Primarily includes financing costs and interest income at the holding company and earnings from investment funds, which are accounted for as equity method investments. The change in earnings was due to gains on debt repurchases, partially offset by higher interest rates and debt levels.

Components significantly contributing to changes in 2025 EPS compared with 2024:


Diluted Earnings (Loss) Per Share	Three Months Ended Dec. 31		Twelve Months Ended Dec. 31
GAAP diluted EPS — 2024	$	0.81	$	3.44

Components of change — 2025 vs. 2024
Higher electric revenues	0.51		1.27
Higher natural gas revenues	0.05		0.29
Higher AFUDC equity & debt	0.09		0.27

Marshall Wildfire settlement (See Note 6)	(0.01)		(0.38)
Higher interest charges	(0.11)		(0.28)
Higher depreciation and amortization	(0.07)		(0.28)
Higher O&M expenses	(0.08)		(0.25)
Higher electric fuel and purchased power (a)	—		(0.23)

Common equity financing	(0.04)		(0.18)
Higher costs of natural gas sold and transported (a)	(0.06)		(0.12)
Other, net	(0.14)		(0.13)
GAAP diluted EPS — 2025	$	0.95	$	3.42
Marshall Wildfire settlement (See Note 6)	0.01		0.38
Ongoing diluted EPS — 2025	$	0.96	$	3.80

(a)Cost of electric fuel and purchased power and natural gas sold and transported are generally recovered through regulatory recovery mechanisms and offset in revenue.

ROE for Xcel Energy and its utility subsidiaries:


2025	NSP-Minnesota		PSCo		SPS		NSP-Wisconsin		Operating Companies		Xcel Energy
GAAP ROE	9.19	%	5.66	%	8.70	%	9.09	%	7.60	%	9.36	%
Ongoing ROE	9.19	%	7.55	%	8.70	%	9.09	%	8.40	%	10.38	%


2024	NSP-Minnesota		PSCo		SPS		NSP-Wisconsin		Operating Companies		Xcel Energy
GAAP ROE	9.07	%	7.63	%	9.57	%	8.98	%	8.55	%	10.42	%
Ongoing ROE	9.46	%	7.63	%	9.57	%	8.98	%	8.69	%	10.61	%

See Note 6 for reconciliation of GAAP earnings to ongoing earnings.

Note 2. Regulated Utility Results

Estimated Impact of Temperature Changes on Regulated Earnings — Unusually hot summers or cold winters increase electric and natural gas sales, while mild weather reduces electric and natural gas sales. The estimated impact of weather on earnings is based on the number of customers, temperature variances, the amount of natural gas or electricity historically used per degree of temperature and excludes any incremental related operating expenses that could result due to storm activity or vegetation management requirements. As a result, weather deviations from normal levels can affect Xcel Energy’s financial performance. However, electric sales true-up and gas decoupling mechanisms in Minnesota predominately mitigate the positive and adverse impacts of weather in that jurisdiction.

Normal weather conditions are defined as either the 10, 20 or 30-year average of actual historical weather conditions. The historical period of time used in the calculation of normal weather differs by jurisdiction, based on regulatory practice. To calculate the impact of weather on demand, a demand factor is applied to the weather impact on sales. Extreme weather variations, windchill and cloud cover may not be reflected in weather-normalized estimates.

Weather — Estimated impact of temperature variations on EPS compared with normal weather conditions:


	Three Months Ended Dec. 31						Twelve Months Ended Dec. 31
	2025 vs. Normal		2024 vs. Normal		2025 vs. 2024		2025 vs. Normal		2024 vs. Normal		2025 vs. 2024
Retail electric	$	(0.014)	$	(0.022)	$	0.008	$	(0.015)	$	(0.008)	$	(0.007)
Decoupling and sales true-up	—		0.007		(0.007)		—		0.047		(0.047)
Electric total	(0.014)		(0.015)		0.001		(0.015)		0.039		(0.054)
Firm natural gas	(0.033)		(0.030)		(0.003)		(0.033)		(0.070)		0.037
Decoupling	0.002		0.009		(0.007)		0.005		0.027		(0.022)
Gas total	(0.031)		(0.021)		(0.010)		(0.028)		(0.043)		0.015
Total	$	(0.045)	$	(0.036)	$	(0.009)	$	(0.043)	$	(0.004)	$	(0.039)

Sales — Sales growth (decline) for actual and weather-normalized sales in 2025 compared to 2024:


	Three Months Ended Dec. 31
	NSP-Minnesota		PSCo		SPS		NSP-Wisconsin		Xcel Energy
Actual
Electric residential	4.6	%	(3.7)	%	0.4	%	5.9	%	1.0	%
Electric C&I	1.1		1.4		3.3		2.1		2.0
Total retail electric sales	2.2		(0.5)		2.8		3.2		1.7
Firm natural gas sales	8.0		(11.1)		N/A		11.8		(3.8)


	Three Months Ended Dec. 31
	NSP-Minnesota		PSCo		SPS		NSP-Wisconsin		Xcel Energy
Weather-normalized
Electric residential	1.3	%	(1.9)	%	2.5	%	2.0	%	0.3	%
Electric C&I	0.5		1.9		3.4		1.4		1.9
Total retail electric sales	0.7		0.4		3.2		1.6		1.4
Firm natural gas sales	0.1		(4.7)		N/A		1.0		(2.9)


	Twelve Months Ended Dec. 31
	NSP-Minnesota		PSCo		SPS		NSP-Wisconsin		Xcel Energy
Actual
Electric residential	5.7	%	(1.6)	%	(1.5)	%	6.0	%	1.9	%
Electric C&I	0.3		0.1		5.5		0.7		2.0
Total retail electric sales	2.0		(0.5)		4.2		2.2		1.9
Firm natural gas sales	12.6		(2.1)		N/A		16.2		3.4


	Twelve Months Ended Dec. 31
	NSP-Minnesota		PSCo		SPS		NSP-Wisconsin		Xcel Energy
Weather-normalized
Electric residential	1.3	%	1.4	%	3.9	%	1.7	%	1.7	%
Electric C&I	(0.6)		1.4		6.1		0.1		2.1
Total retail electric sales	—		1.3		5.6		0.6		2.0
Firm natural gas sales	—		(2.9)		N/A		2.0		(1.7)



	Twelve Months Ended Dec. 31 (2024 Leap Year Adjusted)
	NSP-Minnesota		PSCo		SPS		NSP-Wisconsin		Xcel Energy
Weather-normalized
Electric residential	1.5	%	1.7	%	4.3	%	2.1	%	2.0	%
Electric C&I	(0.3)		1.6		6.3		0.4		2.4
Total retail electric sales	0.3		1.6		5.8		0.9		2.2
Firm natural gas sales	0.6		(2.4)		N/A		2.6		(1.2)

Annual weather-normalized and leap-year adjusted electric sales growth (decline)

•NSP-Minnesota — Residential sales increased due to customer growth (1.1%) and use per customer (0.4%). The decrease in C&I sales was due to lower use per customer.

•PSCo — Residential sales increased due to customer growth (1.1%) and use per customer (0.6%). The increase in C&I sales was due to higher use per customer, particularly in the information and energy sectors.

•SPS — Residential sales increased due to increased use per customer (3.6%) and customer growth (0.7%). The increase in C&I sales was due to higher use per customer, primarily driven by the energy sector.

•NSP-Wisconsin — Residential sales increased due to increased use per customer (1.1%) and customer growth (0.9%). The increase in C&I sales was due to customer growth.

Annual weather-normalized and leap year adjusted natural gas sales growth (decline)

•Decrease in natural gas sales was driven primarily by decreased use per customer in PSCo residential and C&I, partially offset by customer growth in all jurisdictions.

Electric Revenues — Electric revenues are impacted by fluctuations in the price of natural gas, coal and uranium, regulatory outcomes, market prices and seasonality. In addition, electric customers receive a credit for PTCs generated (wind, nuclear, and solar), which reduce electric revenue and income taxes.


(Millions of Dollars)	Three Months Ended Dec. 31, 2025 vs. 2024		Twelve Months Ended Dec. 31, 2025 vs. 2024
Non-fuel riders	$	99	$	250
Recovery of higher cost of electric fuel and purchased power	54		214
PTCs flowed back to customers (offset by lower ETR)	155		172
Regulatory rate outcomes (MN, ND)	18		116
Sales and demand	(1)		97
Transmission revenues	31		79
Sherco Unit 3 2011 outage refunds (See Note 6)	1		47
Estimated impact of weather	—		(39)
Conservation and demand side management (offset in expense)	(4)		(38)





Other, net	46		115
Total increase	$	399	$	1,013

Natural Gas Revenues — Natural gas revenues vary with changing sales, the cost of natural gas and regulatory outcomes.


(Millions of Dollars)	Three Months Ended Dec. 31, 2025 vs. 2024		Twelve Months Ended Dec. 31, 2025 vs. 2024
Recovery of higher cost of natural gas	$	39	$	92
Regulatory rate outcomes (CO)	2		84
Conservation revenue (offset in expense)	13		47
Estimated impact of weather (net of decoupling)	(8)		11
Retail sales decline (net of decoupling)	—		(13)

Other, net	(4)		1

Total increase	$	42	$	222

Electric Fuel and Purchased Power — Expenses incurred for electric fuel and purchased power are impacted by fluctuations in market prices of electricity, natural gas, coal and uranium, as well as seasonality. These incurred expenses are generally recovered through various regulatory recovery mechanisms. As a result, changes in these expenses are largely offset in operating revenues and have minimal earnings impact.

Electric fuel and purchased power expenses increased $173 million in 2025. The increase is primarily due to increased commodity prices and transmission expense.

Cost of Natural Gas Sold and Transported — Expenses incurred for the cost of natural gas sold are impacted by market prices and seasonality. These costs are generally recovered through various regulatory recovery mechanisms. As a result, changes in these expenses are largely offset in operating revenues and have minimal earnings impact.

Natural gas sold and transported increased $90 million in 2025. The increase is primarily due to increased commodity prices and volumes, partially offset by timing of fuel recovery mechanisms.

O&M Expenses — O&M expenses increased $192 million in 2025 primarily due to increased benefits and healthcare costs, wildfire mitigation (largely offset in non-fuel rider revenue), nuclear generation costs and insurance costs.

Depreciation and Amortization — Depreciation and amortization increased $209 million for the year, primarily related to system investment.

Other Income — Other income increased $92 million for the year, primarily related to gains on debt repurchases.

Interest Charges — Interest charges increased $213 million in 2025. The increase was largely due to higher long-term and short-term debt levels and higher interest rates.

AFUDC, Equity and Debt — AFUDC increased $165 million in 2025, due to system investment.

Income Taxes — Effective income tax rate:


	Three Months Ended Dec. 31						Twelve Months Ended Dec. 31
	2025		2024		2025 vs 2024		2025		2024		2025 vs 2024
Federal statutory rate	21.0	%	21.0	%	—	%	21.0	%	21.0	%	—	%
(Decreases) increases in tax from:
Tax credits
PTCs (a)	(48.3)		(183.3)		135.0		(32.3)		(43.2)		10.9
Other	(0.8)		(2.6)		1.8		(0.8)		(1.1)		0.3
Regulatory adjustments (b)	(11.3)		(25.1)		13.8		(6.5)		(6.9)		0.4
State income taxes, net of federal tax effect	7.5		9.9		(2.4)		4.4		3.8		0.6
Other	1.6		2.3		(0.7)		0.4		0.2		0.2
Effective income tax rate	(30.3)	%	(177.8)	%	147.5	%	(13.8)	%	(26.2)	%	12.4	%

(a)Wind, Solar and Nuclear PTCs (net of transfer discounts) are generally credited to customers (reduction to revenue) and do not materially impact earnings.

(b)Regulatory adjustments for income tax primarily relate to the credit of excess deferred taxes to customers. Income tax benefits associated with the credit are offset by corresponding revenue reductions.

Note 3. Capital Structure, Liquidity, Financing and Credit Ratings

Xcel Energy’s capital structure:


(Millions of Dollars)	Dec. 31, 2025		Percentage of Total Capitalization		Dec. 31, 2024		Percentage of Total Capitalization
Current portion of long-term debt	$	501	1	%	$	1,103	2	%
Short-term debt	1,550		3		695		2
Long-term debt	31,832		55		27,316		56
Total debt	33,883		59		29,114		60
Common equity	23,609		41		19,522		40
Total capitalization	$	57,492	100	%	$	48,636	100	%

Liquidity — As of Feb. 2, 2026, Xcel Energy Inc. and its utility subsidiaries had the following committed credit facilities available to meet liquidity needs:


(Millions of Dollars)	Credit Facility (a)		Drawn (b)		Available		Cash		Liquidity
Xcel Energy Inc.	$	2,000	$	825	$	1,175	$	4	$	1,179
PSCo	1,200		435		765		4		769
NSP-Minnesota	800		374		426		6		432
SPS	600		130		470		8		478
NSP-Wisconsin	150		—		150		3		153
Total	$	4,750	$	1,764	$	2,986	$	25	$	3,011
Term Loan (c)	1,500		750		750		—		750

(a)Expires December 2029.

(b)Includes outstanding commercial paper and letters of credit.

(c)Xcel Energy Inc.’s $1.5 billion term loan (entered into in January 2026) matures in January 2027.

Credit Ratings — Access to the capital markets at reasonable terms is partially dependent on credit ratings. The following ratings reflect the views of Moody’s, S&P Global Ratings, and Fitch. The highest credit rating for debt is Aaa/AAA and the lowest investment grade rating is Baa3/BBB-. The highest rating for commercial paper is P-1/A-1/F-1 and the lowest rating is P-3/A-3/F-3. A security rating is not a recommendation to buy, sell or hold securities. Ratings are subject to revision or withdrawal at any time by the credit rating agency and each rating should be evaluated independently of any other rating.

Credit ratings assigned to Xcel Energy Inc. and its utility subsidiaries as of Feb. 2, 2026:

Moody’s

S&P Global Ratings

Fitch

Company

Credit Type

Rating

Outlook

Rating

Outlook

Rating

Outlook

Xcel Energy Inc.

Unsecured

Baa1

Negative

BBB

Stable

BBB+

Stable

NSP-Minnesota

Secured

Aa3

Stable

A+

Stable

NSP-Wisconsin

Secured

Stable

A+

Stable

PSCo

Secured

Negative

A+

Stable

SPS

Secured

Stable

A-

Stable

A-

Stable

Xcel Energy Inc.

Commercial paper

P-2

A-2

NSP-Minnesota

Commercial paper

P-1

A-2

NSP-Wisconsin

Commercial paper

P-2

A-2

PSCo

Commercial paper

P-2

A-2

SPS

Commercial paper

P-2

A-2

Capital Expenditures — Base capital expenditures for Xcel Energy for 2026 through 2030:


	Base Capital Forecast (Millions of Dollars)
By Regulated Utility	2026		2027		2028		2029		2030		Total
NSP-Minnesota	$	3,740	$	4,870	$	4,210	$	3,660	$	3,650	$	20,130
SPS	3,050		5,120		5,350		3,240		2,270		19,030
PSCo	5,980		3,940		2,960		1,760		2,960		17,600
NSP-Wisconsin	910		1,210		760		570		580		4,030
Other (a)	110		(10)		(630)		(210)		(50)		(790)
Total base capital expenditures	$	13,790	$	15,130	$	12,650	$	9,020	$	9,410	$	60,000

(a)Other category includes intercompany transfers for equipment with long lead times.


	Base Capital Forecast (Millions of Dollars)
By Function	2026		2027		2028		2029		2030		Total
Electric transmission	$	3,060	$	2,930	$	2,890	$	3,190	$	3,370	$	15,440
Renewables	3,560		4,620		3,380		1,150		1,210		13,920
Electric distribution	2,920		3,250		2,930		1,680		2,930		13,710
Electric generation	2,220		2,420		2,500		1,810		590		9,540
Natural gas	860		830		700		650		680		3,720
Other	1,170		1,080		250		540		630		3,670

Total base capital expenditures	$	13,790	$	15,130	$	12,650	$	9,020	$	9,410	$	60,000

The plan does not include any potential incremental generation from the current Colorado Near-Term Procurement and Resource Plan, additional future generation RFPs across jurisdictions to fund growth, or additional transmission investments that may come from future planning processes including MISO and SPP. Xcel Energy expects to fund additional capital investment with approximately 40% equity and 60% debt.

Xcel Energy’s capital expenditure forecast is subject to continuing review and modification. Actual capital expenditures may vary from estimates due to changes in electric and natural gas projected load growth, safety and reliability needs, regulatory decisions, legislative initiatives, tax policy, reserve requirements, availability of purchased power, alternative plans for meeting long-term energy needs, environmental initiatives and regulation, and merger, acquisition and divestiture opportunities.

Financing for Capital Expenditures through 2030 — Xcel Energy issues debt and equity securities to refinance retiring debt maturities, reduce short-term debt, fund capital programs, infuse equity in subsidiaries, fund asset acquisitions and for general corporate purposes. Current estimated financing plans of Xcel Energy for 2026-2030 (includes the impact of tax credit transferability)


(Millions of Dollars)
Funding Capital Expenditures
Cash from operations (a)	$	30,180
New debt (b)	22,820
Equity issuances (c)	7,000
Base capital expenditures 2026-2030	$	60,000

Maturing debt	$	3,580

(a)Net of dividends and pension funding.

(b)Reflects a combination of short and long-term debt; net of refinancing.

(c)Amount could include other financing instruments that receive equity credit from the credit rating agencies.

2025 Financing Activity — During 2025, Xcel Energy and its utility subsidiaries issued the following long-term debt:

Issuer

Security

Amount (in millions)

Tenor

Coupon

Xcel Energy Inc.

Senior Unsecured Notes

1,100

3 Year & 10 Year

4.75% & 5.60%

NSP-Minnesota

First Mortgage Bonds

1,100

10 Year & 30 Year

5.05% & 5.65%

PSCo

First Mortgage Bonds

1,000

9 Year & 30 Year

5.35% & 5.85%

PSCo

First Mortgage Bonds

1,000

10 Year & 30 Year

5.15% & 5.85%

SPS

First Mortgage Bonds

500

10 Year

5.30%

NSP-Wisconsin

First Mortgage Bonds

250

29 Year

5.65%

Xcel Energy Inc.

Junior Subordinated Debt

900

60 Year

6.25%

During the year ended Dec. 31, 2025, Xcel Energy Inc. issued shares through a combination of at-the-market cash settlements and physical settlement of certain forward sale agreements for a total of 48.3 million shares ($3.34 billion in net proceeds). Xcel Energy also entered into forward equity agreements and collared forward equity agreements of which 27.2 million shares remain contracted (minimum expected proceeds of $2.02 billion).

2026 Planned Financing Activities — During 2026, Xcel Energy Inc. and its utility subsidiaries anticipate the following long-term debt issuances:

Issuer

Security

Amount (Millions of Dollars)

Xcel Energy Inc.

Senior Unsecured Notes

1,000

PSCo

First Mortgage Bonds

2,400

NSP-Minnesota

First Mortgage Bonds

1,000

SPS

First Mortgage Bonds

1,000

NSP-Wisconsin

First Mortgage Bonds

250

In addition, Xcel Energy plans to issue incremental equity throughout 2026 through its at-the market program or other offerings. Financing plans are subject to change, depending on capital expenditures, regulatory outcomes, internal cash generation, market conditions, changes in tax policies and other factors.

Note 4. Rates, Regulation and Other

NSP-Minnesota — 2024 Minnesota Electric Rate Case — In November 2024, NSP-Minnesota filed an electric rate case in Minnesota based on an ROE of 10.3%, a 52.5% equity ratio and rate base of $13.2 billion in 2025 and $14 billion in 2026. In December 2024, the MPUC approved interim rates of $192 million, effective Jan. 1, 2025. In March 2025, NSP-Minnesota filed supplemental direct testimony, updating its total revenue request to $473 million.

In August 2025, eight parties filed testimony. The Minnesota Department of Commerce (DOC), Office of Attorney General (OAG), Xcel Large Industrial Customers (XLI), the Citizens Utility Board of Minnesota (CUB), Walmart and Joint Intervenors were the only parties to quantify recommended financial adjustments. The DOC and XLI recommended $306 million and $190 million of adjustments, respectively, largely based on a reduction in ROE, certain O&M expenses and other costs offset in trackers. Other parties recommended adjustments based on reduced ROE and issue specific recommendations.

In October 2025, NSP-Minnesota filed rebuttal testimony, updating its total revenue request to $365 million. Of NSP-Minnesota’s proposed adjustments, approximately $100 million relates to depreciation expense and $50 million are largely offset in trackers. In November 2025, the DOC filed surrebuttal testimony, re-asserting their proposed ROE of 9.25%.

An Administrative Law Judge (ALJ) report is expected in April 2026, with a MPUC decision expected in the third quarter of 2026.

NSP-Minnesota — 2025 South Dakota Electric Rate Case — In June 2025, NSP-Minnesota filed a request with the South Dakota Public Utilities Commission (SDPUC) for a net annual electric rate increase of $44 million (15%). The filing is based on a 2024 historic test year, a requested ROE of 10.3%, rate base of approximately $1.2 billion and an equity ratio of 52.87%. Interim rates were implemented on Jan. 1, 2026. If approved as filed, this rate request would result in an average annual residential bill increase of 3% over the period from 2016-2026.

The procedural schedule is as follows:

•Intervenor direct testimony: March 20, 2026

•Rebuttal testimony: April 14, 2026

•Evidentiary Hearing: April 28-30, 2026

A SDPUC decision is expected in the second quarter of 2026.

NSP-Minnesota — 2024 North Dakota Electric Rate Case — In December 2024, NSP-Minnesota filed a request with the North Dakota Public Service Commission (NDPSC) for an annual electric rate increase of $45 million (19.3% over current rates established in 2021). The filing is based on a 2025 forecast test year and includes a requested ROE of 10.3%, rate base of approximately $817 million and an equity ratio of 52.5%. In January 2025, the NDPSC approved interim rates, subject to refund, of approximately $27 million (implemented on Feb. 1, 2025).

In November 2025, NSP-Minnesota filed a settlement agreement along with NDPSC Staff, which would increase the revenue requirement by approximately $24 million, based on a ROE of 9.8% and equity ratio of 52.5%. A NDPSC decision on the settlement and implementation is anticipated in early 2026.

NSP-Minnesota — 2026 North Dakota Natural Gas Rate Case — In January 2026, NSP-Minnesota filed a natural gas rate case in North Dakota, for an annual rate increase of $14 million (11.9%). The filing is based on a 2026 forecast test year and includes an ROE of 10.85%, a 52.5% equity ratio and rate base of $235 million. NSP-Minnesota requested interim rates of $12 million effective April 1, 2026.

NSP-Minnesota — 2025 Minnesota Natural Gas Rate Case — In October 2025, NSP-Minnesota filed a natural gas rate case in Minnesota, seeking a total revenue increase of $63 million (8.2%). The filing is based on a 2026 forecast test year and includes an ROE of 10.65%, a 52.5% equity ratio and rate base of $1.5 billion. NSP-Minnesota requested interim rates of $51 million effective January 1, 2026, which were approved by the MPUC. A MPUC decision is expected in the fourth quarter of 2026.

NSP-Wisconsin — Wisconsin Electric and Natural Gas Rate Case — In March 2025, NSP-Wisconsin filed a request with the Public Service Commission of Wisconsin (PSCW) for a multi-year electric and natural gas rate increase. Both the electric and natural gas rate requests are based on forward-looking 2026 and 2027 test years, with a 10.0% ROE and an equity ratio of 53.5%.

In December 2025, the PSCW issued final written approval on NSP-Wisconsin’s request, with a final rate increase of $126 million for the electric utility ($68 million in 2026, with an incremental $58 million in 2027) and $22 million for the natural gas utility ($18 million in 2026, with an incremental $4 million in 2027), based on a ROE of 9.8% and an equity ratio of 52.5%.

NSP System — Resource Acquisition — In December 2025, NSP-Minnesota and NSP-Wisconsin jointly issued an RFP seeking up to 3,500 MW of wind, solar, hydro, standalone storage, or hybrid capacity that will achieve commercial operation by December 31, 2030. Additionally, NSP-Minnesota is seeking to procure up to 600 MW of solar or solar + storage capacity that will achieve commercial operation by December 31, 2029, and meet Minnesota’s Distributed Solar Energy Standard eligibility requirements. Bids are due in March 2026, and filing for MPUC approval is expected by the end of 2026, ahead of the established procedural schedule.

PSCo — 2025 Colorado Electric Rate Case — In November 2025, PSCo filed an electric rate case with the Colorado Public Utility Commission (CPUC) seeking an increase in revenue of $356 million (9.9%) ($526 million inclusive of rider roll-ins). The request is based on a 9.8% ROE, an equity ratio of 55% and a 2025 test year with a projected rate base of $13 billion.


PSCo’s base rate request (millions of dollars):
Distribution system investment	$	294
Liability insurance	65
Operating costs	51
Changes in cost of capital	49
Coal retirements (a)	(120)
Other	17
Rate request, net of rider roll-ins	$	356

(a)The case includes request for rider recovery of any costs associated with extending operations at Comanche Unit 2.

A CPUC decision and implementation of final rates is anticipated in the third quarter of 2026.

PSCo — 2025 Colorado Natural Gas Rate Case — In December 2025, PSCo filed a natural gas rate case with the CPUC seeking an increase in revenue of $190 million (11.6%). The request is based on a 10.75% ROE, an equity ratio of 55% and a 2025 test year with a projected rate base of $4.7 billion.


PSCo’s base rate request (millions of dollars):
Capital investments	$	90
Changes in cost of capital	53
Operating costs	42
Sales/revenue growth	(7)
Other	12
Total rate request	$	190

A CPUC decision and implementation of final rates is anticipated in the third quarter of 2026.

PSCo — 2024 Colorado Electric Resource Plan — In October 2024, PSCo filed its Phase I electric resource plan with the CPUC. In November 2025, the CPUC approved a load forecast that reflects a 3% compound annual sales growth through 2031 and generation capacity need of approximately 5,400 MW.

PSCo filed a request for reconsideration of various aspects of the decision which were verbally approved in January 2026 with a written decision related to those reconsideration requests expected in the first quarter of 2026. This decision is expected to initiate the Phase II competitive solicitation process with an RFP expected to be issued in the third quarter of 2026. This RFP will seek to acquire the balance of resource needs through 2031 (after consideration of any approved acquisitions from the Near-Term Procurement RFP).

PSCo — Near-Term Procurement — In August 2025, PSCo filed a joint motion with state agencies to initiate a “fast-tracked” solution for tax-advantaged new generation resources. The CPUC approved the request in September 2025 with bids submitted in October 2025. The procurement seeks to accelerate development of up to 4,000 nameplate MW of clean energy resources, 200 accredited MW of firm, dispatchable resources, and up to 300 accredited MW of other dispatchable resources.

The table below summarizes the recommended portfolio of resources filed in December 2025 (a decision is expected in February 2026):


(Nameplate MW)	Company Owned	PPA	Total
Wind	1,600	1,100	2,700
Solar	—	1,100	1,100
Natural gas combustion turbine	200	—	200
Other storage	300	600	900
Total	2,100	2,800	4,900

SPS — 2025 New Mexico Electric Rate Case — In November 2025, SPS filed an electric rate case with the New Mexico Public Regulation Commission (NMPRC) seeking a revenue increase of $175 million (16.7%). The request is based on a future test year period ending November 30, 2027, a ROE of 10.5%, an equity ratio of 56% and retail rate base of $3.9 billion.

The request reflects:

•Significant retail revenue growth.

•Continued capital investment primarily to support the clean energy transition and load growth.

•Planned roll-off of 100 MW of wholesale load in 2026.

SPS’ base rate request (millions of dollars):


Retail revenue growth	$	(204)
Increase in allocation of assets and costs to New Mexico retail, including impact of wholesale load roll-off	148
Capital investment	133
O&M expenses	36
Depreciation rate changes and amortization	34
Increase in requested ROE	28
Total rate request	$	175

The procedural schedule is as follows:

•Intervenor direct testimony: March 27, 2026

•Rebuttal testimony: April 17, 2026

•Public Evidentiary Hearing: May 26 - June 5, 2026

A NMPRC decision and implementation of final rates is anticipated in the second half of 2026.

SPS — SPS Resource Plan (IRP) — In October 2023, SPS filed its IRP with the NMPRC, which supports projected load growth and increasing reliability requirements, and secures replacement energy and capacity for retiring resources.

In July 2024, SPS issued a RFP, seeking approximately 3,200 MW of accredited capacity by 2030. In July 2025, the portfolio selection report was publicly filed with the NMPRC with 3,121 MW of accredited capacity resources, including the following:


Generation Resource Nameplate Capacity (in Megawatts)	Company Owned	Power Purchase Agreements	Total
Wind Resources	1,273	—	1,273
Solar	695	—	695
Storage	472	640	1,112
Natural Gas	2,088	—	2,088
Total	4,528	640	5,168

SPS filed or expects to file Certificate of Convenience and Necessity filings for the specific assets with the PUCT and NMPRC in 2025 and 2026, with approvals expected in 2026 and 2027.

SPS — 2025 Resource Acquisition — In October 2025, SPS issued a RFP to solicit 870 MW of accredited capacity (approximately 1,500 MW to 3,000 MW nameplate capacity) through 2032. Additional resources will be evaluated to meet the New Mexico Renewable Portfolio Standard compliance need. Bids were received in January 2026, and the portfolio is expected to be filed in the second half of 2026.

Note 5. Wildfire Litigation

Marshall Wildfire Litigation —In December 2021, a wildfire ignited in Boulder County, Colorado (Marshall Fire). On June 8, 2023, the Boulder County Sheriff’s Office released its Marshall Fire Investigative Summary and Review and its supporting documents (Sheriff’s Report). According to the Sheriff’s Report, on Dec. 30, 2021, a fire ignited on a residential property in Boulder, Colorado, located in PSCo’s service territory, for reasons unrelated to PSCo’s power lines. According to the Sheriff’s Report, approximately one hour and 20 minutes after the first ignition, a second fire ignited just south of the Marshall Mesa Trailhead in unincorporated Boulder County, Colorado, also located in PSCo’s service territory. According to the Sheriff’s Report, the second ignition started approximately 80 to 110 feet away from PSCo’s power lines in the area.

PSCo received notice or otherwise became aware of 307 complaints on behalf of at least 4,087 plaintiffs, most of which also named Xcel Energy Inc. and Xcel Energy Services Inc. as additional defendants, relating to the Marshall Fire. The complaints generally alleged that PSCo’s equipment ignited the Marshall Fire and asserted various causes of action under Colorado law. In addition to asserting claims against PSCo, Xcel Energy Inc. and Xcel Energy Services Inc., various plaintiffs, including insurance company plaintiffs, asserted claims against certain telecommunications companies (the Telecom Companies). In April 2025, most of the remaining plaintiffs amended their complaints to also assert claims against the Telecom Companies. In June 2025, the Boulder County District Court dismissed Xcel Energy Inc. from the complaints that named that entity as a defendant, due to lack of jurisdiction.

An initial trial on liability issues was scheduled to start in September 2025. Prior to trial, in September 2025, Xcel Energy, Qwest Corporation and Teleport Communications America, LLC reached settlement agreements in principle that resolve all claims asserted by the subrogation insurers, the public entity plaintiffs and individual plaintiffs, and require PSCo to make settlement payments of $640 million. PSCo did not admit any fault, wrongdoing or negligence in connection with these settlement agreements.

As a result of settlements as well as legal and other costs of the matter, PSCo recognized charges to earnings of $287 million and $12 million in the quarterly periods ended Sept. 30 and Dec. 31, 2025, respectively, after consideration of total costs expected to be reimbursed by insurance. As of February 2026, final settlement documentation has been executed with the subrogation insurers, the public entity plaintiffs and nearly all the individual plaintiffs, and nearly all have received payment. If complaints of the remaining individual plaintiffs who have not accepted a settlement or have otherwise stopped prosecuting their claims are not resolved, they may be subject to further litigation.

A remaining estimated liability of $5 million is presented in other current liabilities as of Dec. 31, 2025; no estimated liability was recognized as of Dec. 31, 2024. PSCo records insurance recoveries when it is deemed probable that recovery will occur, and PSCo can reasonably estimate the amount or range. Insurance receivables of $353 million related to settlements are presented in prepayments and other current assets as of Dec. 31, 2025; no such insurance receivables were recognized as of Dec. 31, 2024.

2024 Smokehouse Creek Fire Complex — On February 26, 2024, multiple wildfires began in the Texas Panhandle, including the Smokehouse Creek Fire and the 687 Reamer Fire, which burned into the perimeter of the Smokehouse Creek Fire (together, referred to herein as the “Smokehouse Creek Fire Complex”). The Texas A&M Forest Service issued incident reports that determined that the Smokehouse Creek Fire and the 687 Reamer Fire were caused by power lines owned by SPS after wooden poles near each fire origin failed. According to the Texas A&M Forest Service’s Incident Viewer and news reports, the Smokehouse Creek Fire Complex burned approximately 1,055,000 acres.

SPS is aware of approximately 47 complaints, most of which have also named Xcel Energy Services Inc. as an additional defendant, relating to the Smokehouse Creek Fire Complex. The complaints, which assert claims on behalf of one or more plaintiffs, generally allege that SPS’ equipment ignited the Smokehouse Creek Fire Complex and seek compensation for losses resulting from the fire, asserting various causes of action under Texas law. In addition to seeking compensatory damages, certain of the complaints also seek exemplary damages. Of the 47 complaints, 21 have been resolved and dismissed to date, with one other complaint settled and pending dismissal.

SPS has received 287 claims through its claims process, net of duplicative, withdrawn and denied claims, and has reached final settlements on 222 of those claims as of the date of this filing. In addition to filed complaints and claims made through SPS’ claims process, SPS has also received information from attorneys for approximately 83 claims which have not been submitted through the claims process and have also not been filed as lawsuits and has reached settlement of 79 of those claims through mediation.

SPS has settled claims related to both of the fatalities believed to be associated with the Smokehouse Creek Fire Complex. Settlements have also been reached with the subrogated insurer plaintiffs as well as the three largest claims asserted from the fire, as measured by fire-impacted acreage. Settlements reached as of the date of this filing total $382 million of expected loss payments, of which $374 million and $35 million were paid through Dec. 31, 2025 and 2024, respectively.

In December 2025, the Texas Attorney General’s office filed a lawsuit against SPS regarding the Smokehouse Creek Fire, seeking monetary damages and civil penalties for losses to property and wildlife resulting from the fires.

Based on the current state of the law and the facts and circumstances available as of the date of this filing, Xcel Energy has recorded $430 million of total estimated losses for the matter (before available insurance). A remaining estimated liability of $56 million and $180 million is presented in other current liabilities as of Dec. 31, 2025 and 2024, respectively.

The cumulative estimated probable losses of $430 million for complaints and claims in connection with the Smokehouse Creek Fire Complex (before available insurance) represents the total of actual settlements reached to date plus the low end of the range for remaining reasonably estimable losses, and is subject to change as additional information becomes available. This $430 million estimate does not include amounts for (i) potential penalties or fines that may be imposed by governmental entities on Xcel Energy, (ii) exemplary or punitive damages, (iii) compensation claims by federal, state, county and local government entities or agencies, (iv) unsettled compensation claims for damage to trees and oil and gas equipment, or (v) other amounts that are not reasonably estimable.

Xcel Energy remains unable to reasonably estimate any additional loss or the upper end of the range because there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including whether additional complaints and demands may be made. In the event that SPS or Xcel Energy Services Inc. was found liable related to the litigation related to the Smokehouse Creek Fire Complex and was required to pay damages, such amounts could exceed our insurance coverage of approximately $500 million for the annual policy period and could have a material adverse effect on our financial condition, results of operations or cash flows.

The process for estimating losses associated with potential claims related to the Smokehouse Creek Fire Complex requires management to exercise significant judgment based on a number of assumptions and subjective factors, including the factors identified above and estimates based on currently available information and prior experience with wildfires. As more information becomes available, management estimates and assumptions regarding the potential financial impact of the Smokehouse Creek Fire Complex may change.

Texas law does not apply strict liability in determining an electric utility company’s liability for fire-related damages. For negligence claims under Texas law, a public utility has a duty to exercise ordinary and reasonable care.

Potential liabilities related to the Smokehouse Creek Fire Complex depend on various factors, including the cause of the equipment failure and the extent and magnitude of potential damages, including damages to residential and commercial structures, personal property, vegetation, livestock and livestock feed (including replacement feed), personal injuries and any other damages, penalties, fines or restitution that may be imposed by courts or other governmental entities if SPS is found to have been negligent.

SPS records insurance recoveries when it is deemed probable that recovery will occur, and SPS can reasonably estimate the amount or range. Insurance receivables for estimated losses of approximately $195 million and $210 million, net of recoveries received are presented in prepayments and other current assets as of Dec. 31, 2025 and 2024, respectively. While SPS plans to seek recovery of all insured losses, it is unable to predict the ultimate amount and timing of such insurance recoveries.

Note 6. Non-GAAP Reconciliation

Xcel Energy’s reported earnings are prepared in accordance with GAAP. Xcel Energy’s management believes that ongoing earnings, or GAAP earnings adjusted for certain items, reflect management’s performance in operating the company and provides a meaningful representation of the underlying performance of Xcel Energy’s core business. In addition, Xcel Energy’s management uses ongoing earnings internally for financial planning and analysis, reporting of results to the Board of Directors and when communicating its earnings outlook to analysts and investors. This non-GAAP financial measure should not be considered as an alternative to measures calculated and reported in accordance with GAAP.

Earnings Adjusted for Certain Items (Ongoing Earnings)

Reconciliation of GAAP earnings (net income) to ongoing earnings:


	Three Months Ended Dec. 31				Twelve Months Ended Dec. 31
(Millions of Dollars)	2025		2024		2025		2024
GAAP net income	$	567	$	464	$	2,018	$	1,936


Sherco Unit 3 2011 outage refunds	—		1		—		47
Marshall Wildfire litigation (a)	12		—		298		—
Less: tax effect of adjustment	(3)		—		(77)		(13)
Ongoing earnings (b)	$	576	$	464	$	2,239	$	1,969

(a)Includes $2 million of interest costs associated with short-term debt used to pay settlement, which is presented as interest expense on the consolidated statements of income.

(b)Amounts may not add due to rounding.

Reconciliation of GAAP EPS to ongoing EPS by operating company:


	Twelve Months Ended Dec. 31, 2025						Twelve Months Ended Dec. 31, 2024
Earnings (Loss) Per Share	GAAP Diluted EPS		Impact of Adjustments		Ongoing Diluted EPS		GAAP Diluted EPS		Impact of Adjustments		Ongoing Diluted EPS
NSP-Minnesota	$	1.53	$	—	$	1.53	$	1.41	0.06		$	1.47
PSCo	1.15		0.38		1.53		1.39		$	—	1.39
SPS	0.67		—		0.67		0.70		—		0.70
NSP-Wisconsin	0.27		—		0.27		0.24		—		0.24
Earnings from equity method investments — WYCO	0.03		—		0.03		0.03		—		0.03
Regulated utility (a)	3.65		0.38		4.03		3.76		0.06		3.83
Xcel Energy Inc. and Other	(0.23)		—		(0.23)		(0.33)		—		(0.33)
Total (a)	3.42		0.38		3.80		3.44		0.06		3.50

(a)Amounts may not add due to rounding.

Adjustments to GAAP net income include:

Sherco Unit 3 2011 Outage Refunds — NSP-Minnesota’s Sherco Unit 3 experienced an extended outage following a 2011 incident which damaged its turbine. In October 2024 following contested case procedures, the MPUC ordered a customer refund of $46 million for replacement power incurred during the outage, which is presented as a non-recurring charge to electric revenues.

Marshall Wildfire Litigation — In the third quarter of 2025, PSCo recognized a non-recurring $287 million charge as a result of a settlement reached with the plaintiffs in the Marshall Wildfire litigation. In the fourth quarter of 2025, an additional $12 million was recognized for estimated remaining settlement costs as well as legal and other costs. See Note 5.

Note 7. Earnings Guidance and Long-Term EPS and Dividend Growth Rate Objectives

Xcel Energy 2026 Earnings Guidance — Xcel Energy’s 2026 ongoing earnings guidance is a range of $4.04 to $4.16 per share. (a)

Key assumptions as compared with 2025 actual levels unless noted:

•Constructive outcomes in all pending rate case and regulatory proceedings.

•Normal weather patterns for the year.

•Weather-normalized retail electric sales are projected to increase ~3%.

•Weather-normalized retail firm natural gas sales are projected to increase ~1%.

•Capital rider revenue is projected to increase $535 million to $545 million.

•O&M expenses are projected to increase ~3%.

•Depreciation expense is projected to increase approximately $350 million to $360 million.

•Property taxes are projected to increase $30 million to $40 million.

•Interest expense (net of AFUDC - debt) is projected to increase $300 million to $310 million, net of interest income.

•AFUDC - equity is projected to increase $140 million to $150 million.

(a)Ongoing earnings is calculated using net income and adjusting for certain nonrecurring or infrequent items that are, in management’s view, not reflective of ongoing operations. Ongoing earnings could differ from those prepared in accordance with GAAP for unplanned and/or unknown adjustments. As Xcel Energy is unable to quantify the financial impacts of any additional adjustments that may occur for the year, we are unable to provide a quantitative reconciliation of the guidance for ongoing EPS to corresponding GAAP EPS.

Long-Term EPS and Dividend Growth Rate Objectives — Xcel Energy expects to deliver an attractive total return to our shareholders through a combination of earnings growth and dividend yield, based on the following long-term objectives:

• Deliver long-term annual EPS growth of 6% to 8+% based off of $3.80 per share.

• Deliver annual dividend increases of 4% to 6%.

• Target a dividend payout ratio of 45% to 55%.

• Maintain senior secured debt credit ratings in the A range.

XCEL ENERGY INC. AND SUBSIDIARIES

EARNINGS RELEASE SUMMARY (UNAUDITED)

(amounts in millions, except per share data)



	Three Months Ended Dec. 31
	2025		2024
Operating revenues:
Electric and natural gas	$	3,546	$	3,105
Other	15		15
Total operating revenues	3,561		3,120

Net income	$	567	$	464

Weighted average diluted common shares outstanding	597		576

Components of EPS — Diluted
Regulated utility	$	0.94	$	0.85
Xcel Energy Inc. and other costs	0.01		(0.05)
GAAP diluted EPS (a)	$	0.95	$	0.81
Sherco Unit 3 2011 outage refunds (See Note 6)	—		—
Marshall Wildfire litigation (See Note 6)	0.01		—
Ongoing diluted EPS (a)	$	0.96	$	0.81

Book value per share	$	39.54	$	33.88
Cash dividends declared per common share	0.57		0.5475



	Twelve Months Ended Dec. 31
	2025		2024
Operating revenues:
Electric and natural gas	$	14,612	$	13,377
Other	57		64
Total operating revenues	14,669		13,441

Net income	$	2,018	$	1,936

Weighted average diluted common shares outstanding	589		563

Components of EPS — Diluted
Regulated utility	$	3.65	$	3.76
Xcel Energy Inc. and other costs	(0.23)		(0.33)
GAAP diluted EPS (a)	$	3.42	$	3.44
Sherco Unit 3 2011 outage refunds (See Note 6)	—		0.06
Marshall Wildfire litigation (See Note 6)	0.38		—
Ongoing diluted EPS (a)	$	3.80	$	3.50

Book value per share	$	40.07	$	34.65
Cash dividends declared per common share	2.28		2.19

(a) Amounts may not add due to rounding.