XEL 10-Q
Xcel Energy Inc (XEL)
10-Q
2026-07-30
For: 2026-06-30
View Original
Added on
July 30, 2026
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
| QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |||||
For the quarterly period ended June 30, 2026
or
| 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: 001-3034
| (Exact Name of Registrant as Specified in its Charter) | ||||||||
| (State or Other Jurisdiction of Incorporation or Organization) | (I.R.S. Employer Identification No.) | |||||||||||||||||||
| (Address of Principal Executive Offices) | (Zip Code) | |||||||||||||||||||
| (Registrant’s Telephone Number, Including Area Code) | |||||
| N/A | |||||
| (Former name, former address and former fiscal year, if changed since last report) | |||||
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered | ||||||||||||
Indicate by check mark whether the registrant (1) has 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) has been subject to such filing requirements for the past 90 days. ☒ Yes ☐ No
Indicate by check mark whether the registrant has 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). ☒ Yes ☐ No
Indicate by check mark whether the registrant is 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.
| ☒ | Accelerated filer | ☐ | |||||||||||||||
| Non-accelerated filer | ☐ | Smaller reporting company | |||||||||||||||
| 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. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ☐ Yes ☒ No
Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.
| Class | Outstanding at July 28, 2026 | |||||||
| Common Stock, $2.50 par value | ||||||||
TABLE OF CONTENTS
| PART I | FINANCIAL INFORMATION | ||||||||||
| Item 1 — | |||||||||||
| Item 2 — | |||||||||||
| Item 3 — | |||||||||||
| Item 4 — | |||||||||||
| PART II | OTHER INFORMATION | ||||||||||
| Item 1 — | |||||||||||
| Item 1A — | |||||||||||
| Item 2 — | |||||||||||
| Item 5 — | |||||||||||
| Item 6 — | |||||||||||
This Form 10-Q is filed by Xcel Energy Inc. Additional information is available in various filings with the SEC. This report should be read in its entirety.
2
Definitions of Abbreviations
| Xcel Energy Inc.’s Subsidiaries and Affiliates (current and former) | |||||
| NSP-Minnesota | Northern States Power Company, a Minnesota corporation | ||||
| NSP System | The electric production and transmission system of NSP-Minnesota and NSP-Wisconsin operated on an integrated basis and managed by NSP-Minnesota | ||||
| NSP-Wisconsin | Northern States Power Company, a Wisconsin corporation | ||||
| PSCo | Public Service Company of Colorado | ||||
| SPS | Southwestern Public Service Company | ||||
| Utility subsidiaries | NSP-Minnesota, NSP-Wisconsin, PSCo and SPS | ||||
| WYCO | WYCO Development, LLC | ||||
| Xcel Energy | Xcel Energy Inc. and its subsidiaries | ||||
| Federal and State Regulatory Agencies | |||||
| CPUC | Colorado Public Utilities Commission | ||||
| EPA | United States Environmental Protection Agency | ||||
| FASB | Financial Accounting Standards Board | ||||
| FERC | Federal Energy Regulatory Commission | ||||
| MPSC | Michigan Public Service Commission | ||||
| MPUC | Minnesota Public Utilities Commission | ||||
| NDPSC | North Dakota Public Service Commission | ||||
| NMPRC | New Mexico Public Regulation Commission | ||||
| NRC | Nuclear Regulatory Commission | ||||
| PSCW | Public Service Commission of Wisconsin | ||||
| PUCT | Public Utility Commission of Texas | ||||
| SEC | Securities and Exchange Commission | ||||
| SDPUC | South Dakota Public Utilities Commission | ||||
| Other | |||||
| AFUDC | Allowance for funds used during construction | ||||
| ALJ | Administrative Law Judge | ||||
| ASU | Accounting standards update | ||||
| ATM | At-the-market | ||||
| C&I | Commercial and Industrial | ||||
| CCR | Coal combustion residuals | ||||
| CCN | Certificate of convenience and necessity | ||||
| CCR Rule | Final rule (40 CFR 257.50 - 257.107) published by EPA regulating the management, storage and disposal of CCRs as a nonhazardous waste | ||||
| CDD | Cooling degree-days | ||||
| CEO | Chief executive officer | ||||
| CERCLA | Comprehensive Environmental Response, Compensation, and Liability Act | ||||
| CFO | Chief financial officer | ||||
CO2 | Carbon dioxide | ||||
| DRIP | Dividend Reinvestment and Stock Purchase Program | ||||
| DSM | Demand side management | ||||
| EPS | Earnings per share | ||||
| ETR | Effective tax rate | ||||
| FTR | Financial transmission right | ||||
| GAAP | United States generally accepted accounting principles | ||||
| GHG | Greenhouse Gas | ||||
| HDD | Heating degree-days | ||||
| IPP | Independent power producing entity | ||||
| IRP | Integrated Resource Plan | ||||
| LLC | Limited liability company | ||||
| MGP | Manufactured gas plant | ||||
| MISO | Midcontinent Independent System Operator, Inc. | ||||
| NAV | Net asset value | ||||
| NOx | Nitrogen Oxides | ||||
| O&M | Operating and maintenance | ||||
| PFAS | Per- and Polyfluoroalkyl Substances | ||||
| PPA | Power purchase agreement | ||||
| PTC | Production tax credit | ||||
| RFP | Request for proposal | ||||
| ROE | Return on equity | ||||
| ROU | Right-of-use | ||||
| RPS | Renewable portfolio standard | ||||
| RTO | Regional transmission organization | ||||
| SOFR | Secured overnight financing rate | ||||
| SPP | Southwest Power Pool, Inc. | ||||
| THI | Temperature-humidity index | ||||
| UCA | Colorado Office of the Utility Consumer Advocate | ||||
| VaR | Value at risk | ||||
| VIE | Variable interest entity | ||||
| Measurements | |||||
MMbtu | Million British Thermal Units | ||||
| MW | Megawatts | ||||
| MWh | Megawatt hours | ||||
3
Forward-Looking Statements | ||
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, 2025 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; 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; reputational impacts of actions by employees, directors, or third-parties; our ability to recover costs and our subsidiaries’ ability to recover costs from customers; risks associated with the growth in large load 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.
4
PART I — FINANCIAL INFORMATION
ITEM 1 — FINANCIAL STATEMENTS
XCEL ENERGY INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)
(amounts in millions, except per share data)
| Three Months Ended June 30 | Six Months Ended June 30 | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Operating revenues | |||||||||||||||||||||||
| Electric | $ | $ | $ | $ | |||||||||||||||||||
| Natural gas | |||||||||||||||||||||||
| Other | |||||||||||||||||||||||
| Total operating revenues | |||||||||||||||||||||||
| Operating expenses | |||||||||||||||||||||||
| Electric fuel and purchased power | |||||||||||||||||||||||
| Cost of natural gas sold and transported | |||||||||||||||||||||||
| Cost of sales — other | |||||||||||||||||||||||
| Operating and maintenance expenses | |||||||||||||||||||||||
| Conservation and demand side management expenses | |||||||||||||||||||||||
| Depreciation and amortization | |||||||||||||||||||||||
| Taxes (other than income taxes) | |||||||||||||||||||||||
| Marshall Wildfire litigation | ( | ||||||||||||||||||||||
| Total operating expenses | |||||||||||||||||||||||
| Operating income | |||||||||||||||||||||||
| Other income, net | |||||||||||||||||||||||
| Earnings (loss) from equity method investments | ( | ( | |||||||||||||||||||||
| Allowance for funds used during construction — equity | |||||||||||||||||||||||
| Interest charges and financing costs | |||||||||||||||||||||||
| Interest charges — includes other financing costs | |||||||||||||||||||||||
| Allowance for funds used during construction — debt | ( | ( | ( | ( | |||||||||||||||||||
| Total interest charges and financing costs | |||||||||||||||||||||||
| Income before income taxes | |||||||||||||||||||||||
| Income tax benefit | ( | ( | ( | ( | |||||||||||||||||||
| Net income | $ | $ | $ | $ | |||||||||||||||||||
| Weighted average common shares outstanding: | |||||||||||||||||||||||
| Basic | |||||||||||||||||||||||
| Diluted | |||||||||||||||||||||||
| Earnings per average common share: | |||||||||||||||||||||||
| Basic | $ | $ | $ | $ | |||||||||||||||||||
| Diluted | |||||||||||||||||||||||
| See Notes to Consolidated Financial Statements | |||||||||||||||||||||||
5
XCEL ENERGY INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)
(amounts in millions)
| Three Months Ended June 30 | Six Months Ended June 30 | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Net income | $ | $ | $ | $ | |||||||||||||||||||
| Other comprehensive income | |||||||||||||||||||||||
| Pension and retiree medical benefits: | |||||||||||||||||||||||
| Reclassifications of losses to net income, net of tax | |||||||||||||||||||||||
| Derivative instruments: | |||||||||||||||||||||||
| Net fair value increase, net of tax | |||||||||||||||||||||||
| Reclassification of losses to net income, net of tax | |||||||||||||||||||||||
| Total other comprehensive income | |||||||||||||||||||||||
| Total comprehensive income | $ | $ | $ | $ | |||||||||||||||||||
| See Notes to Consolidated Financial Statements | |||||||||||||||||||||||
6
XCEL ENERGY INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)
(amounts in millions)
| Six Months Ended June 30 | |||||||||||
| 2026 | 2025 | ||||||||||
| Operating activities | |||||||||||
| Net income | $ | $ | |||||||||
| Adjustments to reconcile net income to cash provided by operating activities: | |||||||||||
| Depreciation and amortization | |||||||||||
| Nuclear fuel amortization | |||||||||||
| Deferred income taxes | ( | ||||||||||
| Allowance for equity funds used during construction | ( | ( | |||||||||
| (Earnings) loss from equity method investments | ( | ||||||||||
| Dividends from equity method investments | |||||||||||
| Provision for bad debts | |||||||||||
| Share-based compensation expense | |||||||||||
| Changes in operating assets and liabilities: | |||||||||||
| Accounts receivable | |||||||||||
| Accrued unbilled revenues | |||||||||||
| Inventories | ( | ( | |||||||||
| Other current assets | |||||||||||
| Accounts payable | ( | ( | |||||||||
| Net regulatory assets and liabilities | ( | ||||||||||
| Other current liabilities | ( | ( | |||||||||
| Pension and other employee benefit obligations | ( | ( | |||||||||
| Other, net | ( | ( | |||||||||
| Net cash provided by operating activities | |||||||||||
| Investing activities | |||||||||||
| Capital/construction expenditures | ( | ( | |||||||||
| Purchase of investment securities | ( | ( | |||||||||
| Proceeds from the sale of investment securities | |||||||||||
| Other, net | ( | ||||||||||
| Net cash used in investing activities | ( | ( | |||||||||
| Financing activities | |||||||||||
| Proceeds from short-term borrowings, net | |||||||||||
| Proceeds from issuances of long-term debt | |||||||||||
| Repayments of long-term debt | ( | ( | |||||||||
| Proceeds from issuance of common stock | |||||||||||
| Dividends paid | ( | ( | |||||||||
| Other, net | ( | ||||||||||
| Net cash provided by financing activities | |||||||||||
| Net change in cash, cash equivalents and restricted cash | |||||||||||
| Cash, cash equivalents and restricted cash at beginning of period | |||||||||||
| Cash, cash equivalents and restricted cash at end of period | $ | $ | |||||||||
| Supplemental disclosure of cash flow information: | |||||||||||
| Cash paid for interest (net of amounts capitalized) | $ | ( | $ | ( | |||||||
| Supplemental disclosure of non-cash investing and financing transactions: | |||||||||||
| Accrued property, plant and equipment additions | $ | $ | |||||||||
| Inventory transfers to property, plant and equipment | |||||||||||
| Operating lease and finance lease right-of-use assets | |||||||||||
| Allowance for equity funds used during construction | |||||||||||
| Issuance of common stock for reinvested dividends and/or equity awards | |||||||||||
| See Notes to Consolidated Financial Statements | |||||||||||
7
XCEL ENERGY INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS (UNAUDITED)
(amounts in millions, except share and per share data
| June 30, 2026 | Dec. 31, 2025 | ||||||||||
| Assets | |||||||||||
| Current assets | |||||||||||
| Cash and cash equivalents | $ | $ | |||||||||
| Accounts receivable, net | |||||||||||
| Accrued unbilled revenues | |||||||||||
| Inventories | |||||||||||
| Regulatory assets | |||||||||||
| Derivative instruments | |||||||||||
| Prepayments and other | |||||||||||
| Total current assets | |||||||||||
| Property, plant and equipment, net | |||||||||||
| Other assets | |||||||||||
| Nuclear decommissioning fund and other investments | |||||||||||
| Regulatory assets | |||||||||||
| Derivative instruments | |||||||||||
| Operating lease right-of-use assets | |||||||||||
| Finance lease right-of-use assets | |||||||||||
| Other | |||||||||||
| Total other assets | |||||||||||
| Total assets | $ | $ | |||||||||
| Liabilities and Equity | |||||||||||
| Current liabilities | |||||||||||
| Current portion of long-term debt | $ | $ | |||||||||
| Short-term debt | |||||||||||
| Accounts payable | |||||||||||
| Regulatory liabilities | |||||||||||
| Taxes accrued | |||||||||||
| Accrued interest | |||||||||||
| Dividends payable | |||||||||||
| Derivative instruments | |||||||||||
| Operating lease liabilities | |||||||||||
| Other | |||||||||||
| Total current liabilities | |||||||||||
| Deferred credits and other liabilities | |||||||||||
| Deferred income taxes | |||||||||||
| Regulatory liabilities | |||||||||||
| Asset retirement obligations | |||||||||||
| Derivative instruments | |||||||||||
| Customer advances | |||||||||||
| Pension and employee benefit obligations | |||||||||||
| Operating lease liabilities | |||||||||||
| Finance lease liabilities | |||||||||||
| Other | |||||||||||
| Total deferred credits and other liabilities | |||||||||||
| Commitments and contingencies | |||||||||||
| Long-term debt | |||||||||||
Common stock — | |||||||||||
| Additional paid in capital | |||||||||||
| Retained earnings | |||||||||||
| Accumulated other comprehensive loss | ( | ( | |||||||||
| Total common stockholders’ equity | |||||||||||
| Total liabilities and equity | $ | $ | |||||||||
| See Notes to Consolidated Financial Statements | |||||||||||
8
XCEL ENERGY INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDERS’ EQUITY (UNAUDITED)
(amounts in millions, except per share data; shares in actual amounts)
| Common Stock Issued | Retained Earnings | Accumulated Other Comprehensive Loss | Total Common Stockholders' Equity | ||||||||||||||||||||||||||||||||
| Shares | Par Value | Additional Paid In Capital | |||||||||||||||||||||||||||||||||
| Three Months Ended June 30, 2026 and 2025 | |||||||||||||||||||||||||||||||||||
| Balance at March 31, 2025 | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||
| Net income | |||||||||||||||||||||||||||||||||||
| Other comprehensive income | |||||||||||||||||||||||||||||||||||
Dividends declared on common stock ($ | ( | ( | |||||||||||||||||||||||||||||||||
| Issuances of common stock | |||||||||||||||||||||||||||||||||||
| Share-based compensation | |||||||||||||||||||||||||||||||||||
| Balance at June 30, 2025 | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||
| Balance at March 31, 2026 | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||
| Net income | |||||||||||||||||||||||||||||||||||
| Other comprehensive income | |||||||||||||||||||||||||||||||||||
Dividends declared on common stock ($ | ( | ( | |||||||||||||||||||||||||||||||||
| Issuances of common stock | |||||||||||||||||||||||||||||||||||
| Share-based compensation | |||||||||||||||||||||||||||||||||||
| Balance at June 30, 2026 | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||
| Common Stock Issued | Retained Earnings | Accumulated Other Comprehensive Loss | Total Common Stockholders' Equity | ||||||||||||||||||||||||||||||||
| Shares | Par Value | Additional Paid In Capital | |||||||||||||||||||||||||||||||||
| Six Months Ended June 30, 2026 and 2025 | |||||||||||||||||||||||||||||||||||
| Balance at Dec. 31, 2024 | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||
| Net income | |||||||||||||||||||||||||||||||||||
| Other comprehensive income | |||||||||||||||||||||||||||||||||||
Dividends declared on common stock ($ | ( | ( | |||||||||||||||||||||||||||||||||
| Issuances of common stock | |||||||||||||||||||||||||||||||||||
| Share-based compensation | ( | ||||||||||||||||||||||||||||||||||
| Balance at June 30, 2025 | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||
| Balance at Dec. 31, 2025 | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||
| Net income | |||||||||||||||||||||||||||||||||||
| Other comprehensive income | |||||||||||||||||||||||||||||||||||
Dividends declared on common stock ($ | ( | ( | |||||||||||||||||||||||||||||||||
| Issuances of common stock | |||||||||||||||||||||||||||||||||||
| Share-based compensation | ( | ||||||||||||||||||||||||||||||||||
| Balance at June 30, 2026 | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||
| See Notes to Consolidated Financial Statements | |||||||||||||||||||||||||||||||||||
9
XCEL ENERGY INC. AND SUBSIDIARIES
Notes to Consolidated Financial Statements (UNAUDITED)
In the opinion of management, the accompanying unaudited consolidated financial statements contain all adjustments necessary to present fairly, in accordance with GAAP, the financial position of Xcel Energy as of June 30, 2026 and Dec. 31, 2025; the results of Xcel Energy’s operations, including the components of net income, comprehensive income, and changes in stockholders’ equity for the three and six months ended June 30, 2026 and 2025; and Xcel Energy’s cash flows for the six months ended June 30, 2026 and 2025.
All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after June 30, 2026, up to the date of issuance of these consolidated financial statements. These statements contain all necessary adjustments and disclosures resulting from that evaluation. The Dec. 31, 2025 balance sheet information has been derived from the audited 2025 consolidated financial statements included in the Xcel Energy Inc. Annual Report on Form 10-K for the year ended Dec. 31, 2025.
Notes to the consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with GAAP on an annual basis have been condensed or omitted pursuant to such rules and regulations. For further information, refer to the consolidated financial statements and notes thereto included in the Xcel Energy Inc. Annual Report on Form 10-K for the year ended Dec. 31, 2025, filed with the SEC on Feb. 25, 2026.
Due to the seasonality of Xcel Energy’s electric and natural gas sales, interim results are not necessarily an appropriate base from which to project annual results.
1. Summary of Significant Accounting Policies | ||
The significant accounting policies set forth in Note 1 to the consolidated financial statements in the Xcel Energy Inc. Annual Report on Form 10-K for the year ended Dec. 31, 2025 appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.
2. Accounting Pronouncements | ||
Recently Issued
Disaggregation of Income Statement Expenses — In November 2024, the FASB issued ASU 2024-03 – Expense Disaggregation Disclosures (Subtopic 220-40), which requires disclosure of additional detail for certain categories of income statement expenses. The ASU is effective for annual reporting periods beginning after Dec. 15, 2026 and interim reporting periods beginning after Dec. 15, 2027. Xcel Energy is evaluating the impact of the new disclosure guidance.
Environmental Credits — In May 2026, the FASB issued ASU 2026-02 – Environmental Credits and Environmental Credit Obligations (Topic 818), which establishes accounting and disclosure requirements for certain environmental instruments, including renewable energy credits and emissions allowances, as well as for compliance obligations that will be satisfied with such credits. The ASU is effective for annual and interim periods beginning after Dec. 15, 2027. Xcel Energy is evaluating the impact of the new accounting and disclosure guidance.
| 3. Selected Balance Sheet Data | ||
| (Millions of Dollars) | June 30, 2026 | Dec. 31, 2025 | ||||||||||||
| Accounts receivable, net | ||||||||||||||
| Accounts receivable | $ | $ | ||||||||||||
| Less allowance for bad debts | ( | ( | ||||||||||||
| Accounts receivable, net | $ | $ | ||||||||||||
| (Millions of Dollars) | June 30, 2026 | Dec. 31, 2025 | ||||||||||||
| Inventories | ||||||||||||||
| Materials and supplies | $ | $ | ||||||||||||
| Fuel | ||||||||||||||
| Natural gas | ||||||||||||||
| Total inventories | $ | $ | ||||||||||||
| (Millions of Dollars) | June 30, 2026 | Dec. 31, 2025 | ||||||||||||
| Property, plant and equipment, net | ||||||||||||||
| Electric plant | $ | $ | ||||||||||||
| Natural gas plant | ||||||||||||||
| Common and other property | ||||||||||||||
Plant to be retired (a) | ||||||||||||||
| Construction work in progress | ||||||||||||||
| Total property, plant and equipment | ||||||||||||||
| Less accumulated depreciation | ( | ( | ||||||||||||
| Nuclear fuel | ||||||||||||||
| Less accumulated amortization | ( | ( | ||||||||||||
| Property, plant and equipment, net | $ | $ | ||||||||||||
| 4. Borrowings and Other Financing Instruments | ||
Short-Term Borrowings
Short-Term Debt — Xcel Energy Inc. and its utility subsidiaries meet their short-term liquidity requirements primarily through the issuance of commercial paper and borrowings under their credit facilities and term loan agreements.
Commercial paper and term loan borrowings outstanding for Xcel Energy:
| (Amounts in Millions, Except Interest Rates) | Three Months Ended June 30, 2026 | Year Ended Dec. 31, 2025 | ||||||||||||
| Borrowing limit | $ | $ | ||||||||||||
| Amount outstanding at period end | ||||||||||||||
| Average amount outstanding | ||||||||||||||
| Maximum amount outstanding | ||||||||||||||
| Weighted average interest rate, computed on a daily basis | % | % | ||||||||||||
| Weighted average interest rate at period end | ||||||||||||||
Revolving Credit Facilities — In order to issue commercial paper, Xcel Energy Inc. and its utility subsidiaries must have revolving credit facilities equal to or greater than the commercial paper borrowing limits and cannot issue commercial paper exceeding available credit facility capacity. The lines of credit provide short-term financing in the form of notes payable to banks, letters of credit and back-up support for commercial paper borrowings.
10
As of June 30, 2026, Xcel Energy Inc. and its utility subsidiaries had the following committed revolving credit facilities available:
| (Millions of Dollars) | Credit Facility (a) | Drawn (b) | Available | |||||||||||||||||
| Xcel Energy Inc. | $ | $ | $ | |||||||||||||||||
| PSCo | ||||||||||||||||||||
| NSP-Minnesota | ||||||||||||||||||||
| SPS | ||||||||||||||||||||
| NSP-Wisconsin | ||||||||||||||||||||
| Total | $ | $ | $ | |||||||||||||||||
(a)Expires in December 2029.
(b)Includes outstanding commercial paper and letters of credit.
Xcel Energy Inc., NSP-Minnesota, PSCo, and SPS each have the right to request an extension of the credit facility termination date for two additional one-year periods. NSP-Wisconsin has the right to request an extension of the credit facility termination date for an additional one-year period. All extension requests are subject to majority bank group approval.
All credit facility bank borrowings, outstanding letters of credit and outstanding commercial paper reduce the available capacity of the credit facility. Xcel Energy Inc. and its utility subsidiaries had no
Letters of Credit — Xcel Energy Inc. and its utility subsidiaries use letters of credit, generally with terms of one year, to provide financial guarantees for certain obligations. There were $92
Additionally, in March 2026, NSP-Minnesota, PSCo and SPS each entered into an uncommitted letter of credit agreement with overall limits of $50 million, $50 million and $150 million, respectively, to provide additional letter of credit capacity outside of the revolving credit facilities. As of June 30, 2026, a total of $2 million of letters of credit were outstanding under these continuing letter of credit agreements.
Bilateral Credit Agreement — In April 2026, NSP-Minnesota’s uncommitted bilateral credit agreement was renewed for an additional one-year term. The credit agreement is limited in use to support letters of credit.
As of June 30, 2026 and Dec. 31, 2025, NSP-Minnesota had $69 75
Term Loan Agreement — In January 2026, Xcel Energy Inc. entered into a $1.5 billion, 364-Day Delayed Draw Term Loan Agreement. The loan is unsecured and matures Jan. 30, 2027. The term loan includes one financial covenant, requiring Xcel Energy’s consolidated funded debt to total capitalization ratio to be less than or equal to 70 percent. Interest is at a rate equal to the Term SOFR rate, plus 85.0 basis points, or an alternate base rate. As of June 30, 2026 there was $1.5 billion outstanding under the term loan facility.
Long-Term Borrowings and Other Financing Instruments
During the six months ended June 30, 2026, Xcel Energy Inc. and its utility subsidiaries issued the following:
•Xcel Energy Inc. issued $800 million in aggregate principal amount of 5.75 % Fixed-to-Fixed Reset Rate Junior Subordinated Notes, Series due 2056.
•PSCo issued $700 million in aggregate principal amount of 4.15 % First Mortgage Bonds, Series No. 45 due March 13, 2029 and $600 million in aggregate principal amount of 5.05 % First Mortgage Bonds, Series No. 46 due June 15, 2036.
•NSP-Minnesota issued $600 million in aggregate principal amount of 4.85 % First Mortgage Bonds due May 15, 2036 and $600 million in aggregate principal amount of 5.55 % First Mortgage Bonds due May 15, 2056.
•NSP-Wisconsin issued $250 million in aggregate principal amount of 5.48 % First Mortgage Bonds due June 15, 2041.
•SPS issued $650 million in aggregate principal amount of 5.30 % First Mortgage Bonds due August 15, 2036 and $550 million in aggregate principal amount of 5.875 % First Mortgage Bonds due August 15, 2056.
ATM Equity Offerings — Xcel Energy Inc. filed prospectus supplements in August 2025 and May 2026 under which it may sell up to $4 billion and $4.3 billion of its common stock, respectively, through ATM programs. In addition to the issuance and sale of shares of common stock to or through sales agents, Xcel Energy Inc. also may use these ATM programs to enter into forward sale agreements. As of April 30, 2026, no further transactions will occur under the 2025 ATM program.
Forward Sale Agreements — Under these ATM programs, Xcel Energy Inc. has entered into multiple forward sale agreements in 2026 and 2025 in connection with completed public offerings of Xcel Energy common stock.
The following forward sale agreements remain outstanding as of June 30, 2026:
| Agreements Entered | Common Shares (in millions) | Maturity | Minimum Expected Proceeds (millions of dollars) | ||||||||||||||||||||
| 2025 forward equity agreements | Dec. 2026 to May 2027 (a) | $ | (b) | ||||||||||||||||||||
| 2025 collared forward equity agreements | Dec. 2026 | (c) | |||||||||||||||||||||
| 2026 forward equity agreements | Dec. 2027 to Dec. 2028 (a) | (b) | |||||||||||||||||||||
| 2026 collared forward equity agreements | Dec. 2027 to Dec. 2028 | (c) | |||||||||||||||||||||
(a)Maturity date varies by agreement. Xcel Energy may settle the agreements at any time until final maturity.
(b)Actual cash proceeds will be impacted by the timing of settlement. Forward prices are based on the public offering price (net of underwriting fees), increased for the overnight bank funding rate, less a spread and less expected dividends on Xcel Energy’s common stock during the period the agreements are outstanding.
(c)Minimum expected proceeds reflect the floor price. Actual cash proceeds will be based on an average market price for Xcel Energy’s common stock during a period preceding settlement, subject to the cap price and floor price, which are derived from the public offerings.
If settled in physical shares, stockholders’ equity equal to cash proceeds will be recorded at settlement.
11
The collared forward equity agreements will not be settled until maturity, and net cash settlement and net share settlement are generally unavailable. The 2025 and 2026 forward equity agreements could have been settled at June 30, 2026 with physical delivery of common shares to the banking counterparties in exchange for cash; if Xcel Energy unilaterally elected net cash or net share settlement, these agreements also could have been settled with cash or shares of common stock, as follows:
| Pro-Forma/Hypothetical Transactions | ||||||||||||||||||||
| Agreements Entered | Net Settlement proceeds (payments): | Physical Share Delivery Proceeds (millions of dollars) | ||||||||||||||||||
| Common Shares (in millions) | Net Cash (millions of dollars) | |||||||||||||||||||
| 2025 forward equity agreements | ( | $ | ( | $ | ||||||||||||||||
| 2026 forward equity agreements | ||||||||||||||||||||
Equity through DRIP and Benefits Program — Xcel Energy issued $64 million and $39 million of equity through the DRIP and benefits programs during the six months ended June 30, 2026 and 2025, respectively. The programs allow shareholders to reinvest their dividends directly in Xcel Energy Inc. common stock.
Xcel Energy Inc.’s Purchase of Subsidiary First Mortgage Bonds — During the six months ended June 30, 2026, Xcel Energy Inc. purchased $89 million in aggregate principal amounts of NSP-Minnesota’s 3.60 % First Mortgage Bonds Series due Sept. 15, 2047, 2.90 % First Mortgage Bonds Series due March 1, 2050, 2.60 % First Mortgage Bonds Series due June 1, 2051 and 3.20 % First Mortgage Bonds Series due April 1, 2052, for $59 million. During the six months ended June 30, 2025, Xcel Energy Inc. purchased $128 million of NSP-Minnesota first mortgage bonds for $81 million.
During the six months ended June 30, 2026, Xcel Energy Inc. purchased $4 million in aggregate principal amounts of SPS’ 3.70 % First Mortgage Bonds due August 15, 2047, 4.40 % First Mortgage Bonds Series due November 15, 2048 and 3.75 % First Mortgage Bonds due June 15, 2049, for $3 million. Xcel Energy Inc. purchased no SPS first mortgage bonds in 2025.
5. Revenues | ||
Revenue is classified by the type of goods/services rendered and market/customer type. Xcel Energy’s operating revenues consisted of the following:
| Three Months Ended June 30, 2026 | ||||||||||||||||||||||||||
| (Millions of Dollars) | Electric | Natural Gas | All Other | Total | ||||||||||||||||||||||
| Major revenue types | ||||||||||||||||||||||||||
| Revenue from contracts with customers: | ||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | ||||||||||||||||||||||
| C&I | ||||||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||
| Total retail | ||||||||||||||||||||||||||
| Wholesale | ||||||||||||||||||||||||||
| Transmission | ||||||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||
| Total revenue from contracts with customers | ||||||||||||||||||||||||||
| Alternative revenue and other | ||||||||||||||||||||||||||
| Total revenues | $ | $ | $ | $ | ||||||||||||||||||||||
| Three Months Ended June 30, 2025 | ||||||||||||||||||||||||||
| (Millions of Dollars) | Electric | Natural Gas | All Other | Total | ||||||||||||||||||||||
| Major revenue types | ||||||||||||||||||||||||||
| Revenue from contracts with customers: | ||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | ||||||||||||||||||||||
| C&I | ||||||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||
| Total retail | ||||||||||||||||||||||||||
| Wholesale | ||||||||||||||||||||||||||
| Transmission | ||||||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||
| Total revenue from contracts with customers | ||||||||||||||||||||||||||
| Alternative revenue and other | ||||||||||||||||||||||||||
| Total revenues | $ | $ | $ | $ | ||||||||||||||||||||||
| Six Months Ended June 30, 2026 | ||||||||||||||||||||||||||
| (Millions of Dollars) | Electric | Natural Gas | All Other | Total | ||||||||||||||||||||||
| Major revenue types | ||||||||||||||||||||||||||
| Revenue from contracts with customers: | ||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | ||||||||||||||||||||||
| C&I | ||||||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||
| Total retail | ||||||||||||||||||||||||||
| Wholesale | ||||||||||||||||||||||||||
| Transmission | ||||||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||
| Total revenue from contracts with customers | ||||||||||||||||||||||||||
| Alternative revenue and other | ||||||||||||||||||||||||||
| Total revenues | $ | $ | $ | $ | ||||||||||||||||||||||
12
| Six Months Ended June 30, 2025 | ||||||||||||||||||||||||||
| (Millions of Dollars) | Electric | Natural Gas | All Other | Total | ||||||||||||||||||||||
| Major revenue types | ||||||||||||||||||||||||||
| Revenue from contracts with customers: | ||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | ||||||||||||||||||||||
| C&I | ||||||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||
| Total retail | ||||||||||||||||||||||||||
| Wholesale | ||||||||||||||||||||||||||
| Transmission | ||||||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||
| Total revenue from contracts with customers | ||||||||||||||||||||||||||
| Alternative revenue and other | ||||||||||||||||||||||||||
| Total revenues | $ | $ | $ | $ | ||||||||||||||||||||||
| 6. Income Taxes | ||
Total income tax expense from operations differs from the amount computed by applying the statutory federal income tax rate to income before income tax expense.
Effective income tax reconciliation:
| Three Months Ended June 30 | Six Months Ended June 30 | |||||||||||||||||||||||||
| (Millions of Dollars) | 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||||
| Income before income taxes (domestic) | $ | $ | $ | $ | ||||||||||||||||||||||
| Federal statutory rate impact | ||||||||||||||||||||||||||
| (Decreases) increases in tax from: | ||||||||||||||||||||||||||
| Tax credits | ||||||||||||||||||||||||||
PTCs (a) | ( | ( | ( | ( | ||||||||||||||||||||||
| Other | ( | ( | ( | ( | ||||||||||||||||||||||
Regulatory adjustments (b) | ||||||||||||||||||||||||||
| AFUDC equity | ( | ( | ( | ( | ||||||||||||||||||||||
| Plant related excess deferred taxes | ( | ( | ( | ( | ||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||
State income taxes, net of federal tax effect (c) | ||||||||||||||||||||||||||
| Other | ( | ( | ( | |||||||||||||||||||||||
| Income tax benefit | $ | ( | $ | ( | $ | ( | $ | ( | ||||||||||||||||||
| Three Months Ended June 30 | Six Months Ended June 30 | |||||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||||||
| Federal statutory rate | % | % | % | % | ||||||||||||||||||||||
| (Decreases) increases in tax from: | ||||||||||||||||||||||||||
| Tax credits | ||||||||||||||||||||||||||
PTCs (a) | ( | ( | ( | ( | ||||||||||||||||||||||
| Other | ( | ( | ( | ( | ||||||||||||||||||||||
Regulatory adjustments (b) | ||||||||||||||||||||||||||
| AFUDC equity | ( | ( | ( | ( | ||||||||||||||||||||||
| Plant related excess deferred taxes | ( | ( | ( | ( | ||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||
State income taxes, net of federal tax effect (c) | ||||||||||||||||||||||||||
| Other | ( | ( | ||||||||||||||||||||||||
| Effective income tax rate | ( | % | ( | % | ( | % | ( | % | ||||||||||||||||||
(a)Wind and Solar PTCs (net of transfer discounts) are generally credited to customers (reduction to revenue) and do not materially impact earnings.
(b)Regulatory adjustments primarily relate to the credit of plant related excess deferred taxes to customers for tax rate changes as well as the capitalization of AFUDC equity for book purposes only. Income tax benefits associated with the credit of excess deferred taxes are offset by corresponding revenue reductions.
(c)State and local income taxes are primarily Minnesota and Colorado state taxes.
7. Earnings Per Share | ||
Basic EPS was computed by dividing the earnings available to common shareholders by the weighted average number of common shares outstanding. Diluted EPS was computed by dividing the earnings available to common shareholders by the diluted weighted average number of common shares outstanding.
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.
Common Stock Equivalents — Common stock equivalents include commitments to issue common stock related to forward equity agreements, collared forward equity agreements and time-based equity compensation awards. To the extent dilutive, these items are included in diluted shares outstanding using the treasury stock method.
Stock equivalent units granted to Xcel Energy Inc.’s Board of Directors are included in common shares outstanding upon grant date as there is no further service, performance or market condition associated with these awards. Restricted stock issued to employees is included in common shares outstanding when granted.
Share-based compensation arrangements for which there is currently no dilutive impact to EPS include the following:
•Equity awards subject to a performance condition; included in common shares outstanding when all necessary conditions have been satisfied by the end of the reporting period.
•Liability awards subject to a performance condition; any portions settled in shares are included in common shares outstanding upon settlement.
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Common shares outstanding used in the basic and diluted EPS computation:
| Three Months Ended June 30 | Six Months Ended June 30 | |||||||||||||||||||||||||
| (Shares in Millions) | 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||||
| Basic | ||||||||||||||||||||||||||
Diluted (a) | ||||||||||||||||||||||||||
(a)Diluted common shares outstanding included common stock equivalents of 2.3 million and 2.0 million for the three months ended June 30, 2026 and 2025, respectively. Diluted common shares outstanding included common stock equivalents of 2.1 million and 1.7 million for the six months ended June 30, 2026 and 2025, respectively.
8. Fair Value of Financial Assets and Liabilities | ||
Fair Value Measurements
Accounting guidance for fair value measurements and disclosures provides a hierarchical framework for disclosing the observability of the inputs utilized in measuring assets and liabilities at fair value.
•Level 1 — Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. The types of assets and liabilities included in Level 1 are actively traded instruments with observable actual trading prices.
•Level 2 — Pricing inputs are other than actual trading prices in active markets but are either directly or indirectly observable as of the reporting date. The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts or priced with models using highly observable inputs.
•Level 3 — Significant inputs to pricing have little or no observability as of the reporting date. The types of assets and liabilities included in Level 3 include those valued with models requiring significant judgment or estimation.
Specific valuation methods include:
Investments in equity securities and other funds — Equity securities are valued using quoted prices in active markets. The fair values for commingled funds are measured using NAVs. The investments in commingled funds may be redeemed for NAV with proper notice. Private equity commingled funds require approval of the fund for any unscheduled redemption, and such redemptions may be approved or denied by the fund at its sole discretion. Unscheduled distributions from real estate commingled funds may be redeemed with proper notice, however, withdrawals may be delayed or discounted as a result of fund illiquidity.
Investments in debt securities — Fair values for debt securities are determined by a third party pricing service using recent trades and observable spreads from benchmark interest rates for similar securities.
Interest rate derivatives — Fair values of interest rate derivatives are based on broker quotes that utilize current market interest rate forecasts.
Commodity derivatives — Methods used to measure the fair value of commodity derivative forwards and options utilize forward prices and volatilities, as well as pricing adjustments for specific delivery locations, and are generally assigned a Level 2 classification. When contracts relate to inactive delivery locations or extend to periods beyond those readily observable on active exchanges, the significance of the use of less observable inputs on a valuation is evaluated and may result in Level 3 classification.
Electric commodity derivatives held by NSP-Minnesota and SPS include transmission congestion instruments, generally referred to as FTRs. FTRs purchased from an RTO are financial instruments that entitle or obligate the holder to monthly revenues or charges based on transmission congestion across a given transmission path.
The values of these instruments are derived from, and designed to offset, the costs of transmission congestion. In addition to overall transmission load, congestion is also influenced by the operating schedules of power plants and the consumption of electricity pertinent to a given transmission path. Unplanned plant outages, scheduled plant maintenance, changes in the relative costs of fuels used in generation, weather and overall changes in demand for electricity can each impact the operating schedules of the power plants on the transmission grid and the value of these instruments.
FTRs are recognized at fair value and adjusted each period prior to settlement. Given the limited observability of certain variables underlying the reported auction values of FTRs, these fair value measurements have been assigned a Level 3 classification.
Net congestion costs, including the impact of FTR settlements, are shared through fuel and purchased energy cost recovery mechanisms. As such, the fair value of the unsettled instruments (i.e., derivative asset or liability) is offset/deferred as a regulatory asset or liability.
Non-Derivative Fair Value Measurements
Nuclear Decommissioning Fund
The NRC requires NSP-Minnesota to maintain a portfolio of investments to fund the costs of decommissioning its nuclear generating plants. Assets of the nuclear decommissioning fund are legally restricted for the purpose of decommissioning these facilities. The fund contains cash equivalents, debt securities, equity securities and other investments. NSP-Minnesota uses the MPUC approved asset allocation for the investment targets by asset class for the qualified trust.
NSP-Minnesota recognizes the costs of funding the decommissioning over the lives of the nuclear plants, assuming rate recovery of all costs. Realized and unrealized gains on fund investments over the life of the fund are deferred as an offset of NSP-Minnesota’s regulatory asset or as a regulatory liability (dependent on funding status) for nuclear decommissioning costs. Consequently, any realized and unrealized gains and losses on securities in the nuclear decommissioning fund are deferred as a component of the regulatory asset/liability.
Unrealized gains for the nuclear decommissioning fund were $2.0 billion and $1.8 billion as of June 30, 2026 and Dec. 31, 2025, respectively, and unrealized losses were $47
14
Non-derivative instruments with recurring fair value measurements in the nuclear decommissioning fund:
| June 30, 2026 | ||||||||||||||||||||||||||||||||||||||
| Fair Value | ||||||||||||||||||||||||||||||||||||||
| (Millions of Dollars) | Cost | Level 1 | Level 2 | Level 3 | NAV | Total | ||||||||||||||||||||||||||||||||
Nuclear decommissioning fund (a) | ||||||||||||||||||||||||||||||||||||||
| Cash equivalents | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||
| Commingled funds | ||||||||||||||||||||||||||||||||||||||
| Debt securities | ||||||||||||||||||||||||||||||||||||||
| Equity securities | ||||||||||||||||||||||||||||||||||||||
| Total | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||
(a)Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $321 million of equity method investments and $178 million of rabbi trust assets and other miscellaneous investments.
| Dec. 31, 2025 | ||||||||||||||||||||||||||||||||||||||
| Fair Value | ||||||||||||||||||||||||||||||||||||||
| (Millions of Dollars) | Cost | Level 1 | Level 2 | Level 3 | NAV | Total | ||||||||||||||||||||||||||||||||
Nuclear decommissioning fund (a) | ||||||||||||||||||||||||||||||||||||||
| Cash equivalents | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||
| Commingled funds | ||||||||||||||||||||||||||||||||||||||
| Debt securities | ||||||||||||||||||||||||||||||||||||||
| Equity securities | ||||||||||||||||||||||||||||||||||||||
| Total | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||
(a)Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $285 million of equity method investments and $164 million of rabbi trust assets and other miscellaneous investments.
For the three and six months ended June 30, 2026 and 2025, there were no transfers of Level 3 investments between levels.
Contractual maturity dates of debt securities in the nuclear decommissioning fund as of June 30, 2026:
| Final Contractual Maturity | ||||||||||||||||||||||||||||||||
| (Millions of Dollars) | Due in 1 Year or Less | Due in 1 to 5 Years | Due in 5 to 10 Years | Due after 10 Years | Total | |||||||||||||||||||||||||||
| Debt securities | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||
Rabbi Trusts
Xcel Energy has established rabbi trusts to provide partial funding for future deferred compensation plan distributions. The fair value of assets held in the rabbi trusts were $116 million and $107 million as of June 30, 2026 and Dec. 31, 2025, respectively, comprised of cash equivalents and mutual funds (level 1 valuation methods). Amounts are reported in nuclear decommissioning fund and other investments on the consolidated balance sheet.
Derivative Activities and Fair Value Measurements
Xcel Energy enters into derivative instruments, including forward contracts, futures, swaps and options, for trading purposes and to manage risk in connection with changes in interest rates and utility commodity prices.
Interest Rate Derivatives — Xcel Energy enters into contracts that effectively fix the interest rate on a specified principal amount of a hypothetical future debt issuance. These financial swaps net settle based on changes in a specified benchmark interest rate, acting as a hedge of changes in market interest rates that will impact specified anticipated debt issuances. These derivative instruments are designated as cash flow hedges for accounting purposes, with changes in fair value prior to occurrence of the hedged transactions recorded as other comprehensive income.
As of June 30, 2026, accumulated other comprehensive loss related to interest rate derivatives included $3 million of net losses expected to be reclassified into earnings during the next 12 months as the hedged transactions impact earnings. As of June 30, 2026, Xcel Energy had unsettled interest rate derivatives with a notional amount of $130 million.
See Note 11 for the financial impact of qualifying interest rate cash flow hedges on Xcel Energy’s accumulated other comprehensive loss included in the consolidated statements of common stockholder’s equity and in the consolidated statements of comprehensive income.
Wholesale and Commodity Trading — Xcel Energy Inc.’s utility subsidiaries conduct various wholesale and commodity trading activities, including the purchase and sale of electric capacity, energy, energy-related instruments and natural gas-related instruments, including derivatives. Xcel Energy is allowed to conduct these activities within guidelines and limitations as approved by its risk management committee, comprised of management personnel not directly involved in the activities governed by this policy.
Results of derivative instrument transactions entered into for trading purposes are presented in the consolidated statements of income as electric revenues, net of any sharing with customers. These activities are not intended to mitigate commodity price risk associated with regulated electric and natural gas operations. Sharing of these margins is determined through state regulatory proceedings as well as the operation of the FERC-approved joint operating agreement.
Commodity Derivatives — Xcel Energy enters into derivative instruments to manage variability of future cash flows from changes in commodity prices in its electric and natural gas operations. This could include the purchase or sale of energy or energy-related products, natural gas to generate electric energy, natural gas for resale and FTRs.
The most significant derivative positions outstanding at June 30, 2026 and Dec. 31, 2025 for this purpose relate to FTR instruments administered by MISO and SPP. These instruments are intended to offset the impacts of transmission system congestion.
When Xcel Energy enters into derivative instruments that mitigate commodity price risk on behalf of electric and natural gas customers, the instruments are not typically designated as qualifying hedging transactions. The classification of unrealized losses or gains on these instruments as a regulatory asset or liability, if applicable, is based on approved regulatory recovery mechanisms.
As of June 30, 2026, Xcel Energy had no commodity contracts designated as cash flow hedges.
15
Gross notional amounts of commodity forwards, options and FTRs:
(Amounts in Millions) (a)(b) | June 30, 2026 | Dec. 31, 2025 | ||||||||||||
| MWh of electricity | ||||||||||||||
| MMBtu of natural gas | ||||||||||||||
(a)Not reflective of net positions in the underlying commodities.
(b)Notional amounts for options included on a gross basis but weighted for the probability of exercise.
Consideration of Credit Risk and Concentrations — Xcel Energy continuously monitors the creditworthiness of counterparties to its interest rate derivatives and commodity derivative contracts prior to settlement and assesses each counterparty’s ability to perform on the transactions set forth in the contracts. Impact of credit risk was immaterial to the fair value of unsettled commodity derivatives presented on the consolidated balance sheets.
Xcel Energy’s utility subsidiaries’ often have significant concentrations of credit risk with particular entities or industries in their wholesale, trading and non-trading commodity activities.
As of June 30, 2026, two of Xcel Energy’s ten most significant counterparties for these activities, comprising $26 million, or 21 %, of this credit exposure, had investment grade credit ratings from S&P Global Ratings, Moody’s Investor Services or Fitch Ratings.
Credit Related Contingent Features — Contract provisions for derivative instruments that the utility subsidiaries enter, including those accounted for as normal purchase and normal sale contracts and therefore not reflected on the consolidated balance sheets, may require the posting of collateral or settlement of the contracts for various reasons, including if the applicable utility subsidiary’s credit ratings are downgraded below its investment grade credit rating by any of the major credit rating agencies.
As of June 30, 2026 and Dec. 31, 2025, there were $4 million and $7 million of derivative liabilities with such underlying contract provisions.
Certain contracts also contain cross default provisions that may require the posting of collateral or settlement of the contracts if there was a failure under other financing arrangements related to payment terms or other covenants.
As of June 30, 2026 and Dec. 31, 2025, there were approximately $43 million and $62 million of derivative liabilities with such underlying contract provisions, respectively.
Certain derivative instruments are also subject to contract provisions that contain adequate assurance clauses. These provisions allow counterparties to seek performance assurance, including cash collateral, in the event that a given utility subsidiary’s ability to fulfill its contractual obligations is reasonably expected to be impaired.
Xcel Energy had no
Recurring Derivative Fair Value Measurements
Interest rate cash flow hedge gains and losses reclassified into interest expense from accumulated other comprehensive loss were immaterial for the three and six months ended June 30, 2026 and 2025.
Other impacts of derivative activity:
| Pre-Tax Fair Value Gains (Losses) Recognized During the Period in: | ||||||||||||||
| (Millions of Dollars) | Accumulated Other Comprehensive Loss | Regulatory Assets and Liabilities | ||||||||||||
| Three Months Ended June 30, 2026 | ||||||||||||||
| Other derivative instruments: | ||||||||||||||
| Electric commodity | $ | $ | ( | |||||||||||
| Total | $ | $ | ( | |||||||||||
| Six Months Ended June 30, 2026 | ||||||||||||||
| Derivatives designated as cash flow hedges: | ||||||||||||||
| Interest rate | $ | $ | ||||||||||||
| Total | $ | $ | ||||||||||||
| Other derivative instruments: | ||||||||||||||
| Electric commodity | $ | $ | ( | |||||||||||
| Natural gas commodity | ||||||||||||||
| Total | $ | $ | ( | |||||||||||
| Three Months Ended June 30, 2025 | ||||||||||||||
| Derivatives designated as cash flow hedges: | ||||||||||||||
| Interest rate | $ | $ | ||||||||||||
| Total | $ | $ | ||||||||||||
| Other derivative instruments: | ||||||||||||||
| Electric commodity | $ | $ | ||||||||||||
| Total | $ | $ | ||||||||||||
| Six Months Ended June 30, 2025 | ||||||||||||||
| Derivatives designated as cash flow hedges: | ||||||||||||||
| Interest rate | $ | $ | ||||||||||||
| Total | $ | $ | ||||||||||||
| Other derivative instruments: | ||||||||||||||
| Electric commodity | $ | $ | ||||||||||||
| Natural gas commodity | ||||||||||||||
| Total | $ | $ | ||||||||||||
16
| Pre-Tax (Gains) Losses Reclassified into Income During the Period from Regulatory Assets and Liabilities | Pre-Tax Gains (Losses) Recognized During the Period in Income | ||||||||||||||||
| (Millions of Dollars) | |||||||||||||||||
| Three Months Ended June 30, 2026 | |||||||||||||||||
| Other derivative instruments: | |||||||||||||||||
| Electric commodity | $ | (a) | $ | ||||||||||||||
| Total | $ | $ | |||||||||||||||
| Six Months Ended June 30, 2026 | |||||||||||||||||
| Other derivative instruments: | |||||||||||||||||
| Commodity trading | $ | $ | (b) | ||||||||||||||
| Electric commodity | ( | (a) | |||||||||||||||
| Natural gas commodity | ( | (c) (d) | |||||||||||||||
| Total | $ | ( | $ | ( | |||||||||||||
| Three Months Ended June 30, 2025 | |||||||||||||||||
| Other derivative instruments: | |||||||||||||||||
| Commodity trading | $ | $ | (b) | ||||||||||||||
| Electric commodity | ( | (a) | |||||||||||||||
| Total | $ | ( | $ | ||||||||||||||
| Six Months Ended June 30, 2025 | |||||||||||||||||
| Other derivative instruments: | |||||||||||||||||
| Commodity trading | $ | $ | ( | (b) | |||||||||||||
| Electric commodity | ( | (a) | |||||||||||||||
| Natural gas commodity | ( | (c) (d) | |||||||||||||||
| Total | $ | ( | $ | ( | |||||||||||||
(a)Recorded to electric fuel and purchased power. These derivative settlement gains and losses are shared with electric customers through fuel and purchased energy cost-recovery mechanisms, and reclassified out of income as regulatory assets or liabilities, as appropriate. FTR settlements are shared with customers and do not have a material impact on net income. Presented amounts reflect changes in fair value between auction and settlement dates, but exclude the original auction fair value.
(b)Recorded to electric revenues. Presented amounts do not reflect non-derivative transactions or margin sharing with customers.
(c)Amounts are primarily recorded to cost of natural gas sold and transported. Amounts are subject to cost recovery mechanisms and reclassified out of income to a regulatory asset, as appropriate.
(d)Relates primarily to option premium amortization .
Xcel Energy had no
17
Derivative assets and liabilities measured at fair value on a recurring basis were as follows:
| June 30, 2026 | Dec. 31, 2025 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Fair Value | Fair Value Total | Netting (a) | Total | Fair Value | Fair Value Total | Netting (a) | Total | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (Millions of Dollars) | Level 1 | Level 2 | Level 3 | Level 1 | Level 2 | Level 3 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Current derivative assets | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivatives designated as cash flow hedges: | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Interest rate | $ | $ | $ | $ | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other derivative instruments: | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Commodity trading | $ | $ | $ | $ | $ | ( | $ | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Electric commodity | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Natural gas commodity | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total current derivative assets | $ | $ | $ | $ | $ | ( | $ | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Noncurrent derivative assets | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other derivative instruments: | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Commodity trading | $ | $ | $ | $ | $ | ( | $ | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total noncurrent derivative assets | $ | $ | $ | $ | $ | ( | $ | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| June 30, 2026 | Dec. 31, 2025 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Fair Value | Fair Value Total | Netting (a) | Total | Fair Value | Fair Value Total | Netting (a) | Total | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (Millions of Dollars) | Level 1 | Level 2 | Level 3 | Level 1 | Level 2 | Level 3 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Current derivative liabilities | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other derivative instruments: | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Commodity trading | $ | $ | $ | $ | $ | ( | $ | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Electric commodity | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Natural gas commodity | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total current derivative liabilities | $ | $ | $ | $ | $ | ( | $ | $ | $ | $ | $ | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
PPAs (b) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Current derivative instruments | $ | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Noncurrent derivative liabilities | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other derivative instruments: | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Commodity trading | $ | $ | $ | $ | $ | ( | $ | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total noncurrent derivative liabilities | $ | $ | $ | $ | $ | ( | $ | $ | $ | $ | $ | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
PPAs (b) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Noncurrent derivative instruments | $ | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
(a)Xcel Energy nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement. At June 30, 2026 and Dec. 31, 2025, derivative assets and liabilities include no 10 million and $4 million, respectively. Counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.
(b)Xcel Energy currently applies the normal purchase exception to qualifying PPAs. Balance relates to specific contracts that were previously recognized at fair value prior to applying the normal purchase exception, and are being amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities.
18
Changes in Level 3 commodity derivatives:
| Three Months Ended June 30 | ||||||||||||||
| (Millions of Dollars) | 2026 | 2025 | ||||||||||||
| Balance at April 1 | $ | $ | ||||||||||||
Purchases (a) | ||||||||||||||
Settlements (a) | ( | ( | ||||||||||||
| Net transactions recorded during the period: | ||||||||||||||
Losses recognized in earnings (b) | ( | ( | ||||||||||||
Net (losses) gains recognized as regulatory assets and liabilities (a) | ( | |||||||||||||
| Balance at June 30 | $ | $ | ||||||||||||
| Six Months Ended June 30 | ||||||||||||||
| (Millions of Dollars) | 2026 | 2025 | ||||||||||||
| Balance at Jan. 1 | $ | $ | ||||||||||||
Purchases (a) | ||||||||||||||
Settlements (a) | ( | ( | ||||||||||||
| Net transactions recorded during the period: | ||||||||||||||
Losses recognized in earnings (b) | ( | ( | ||||||||||||
Net (losses) gains recognized as regulatory assets and liabilities (a) | ( | |||||||||||||
| Balance at June 30 | $ | $ | ||||||||||||
(a)Relates primarily to NSP-Minnesota and SPS FTR instruments administered by MISO and SPP.
(b)Relates to commodity trading and is subject to offsetting losses and gains on derivative instruments categorized as levels 1 and 2 in the income statement. See above tables for the income statement impact of derivative activity, including commodity trading gains and losses.
Fair Value of Long-Term Debt
Other financial instruments for which the carrying amount did not equal fair value:
| June 30, 2026 | Dec. 31, 2025 | |||||||||||||||||||||||||
| (Millions of Dollars) | Carrying Amount | Fair Value | Carrying Amount | Fair Value | ||||||||||||||||||||||
| Long-term debt, including current portion | $ | $ | $ | $ | ||||||||||||||||||||||
Fair value of Xcel Energy’s long-term debt is estimated based on recent trades and observable spreads from benchmark interest rates for similar securities. Fair value estimates are based on information available to management as of June 30, 2026 and Dec. 31, 2025, and given the observability of the inputs, fair values presented for long-term debt were assigned as Level 2.
9. Benefit Plans and Other Postretirement Benefits | ||
Components of Net Periodic Benefit Cost (Credit)
| Three Months Ended June 30 | ||||||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||||||
| (Millions of Dollars) | Pension Benefits | Postretirement Health Care Benefits | ||||||||||||||||||||||||
| Service cost | $ | $ | $ | $ | ||||||||||||||||||||||
Interest cost (a) | ||||||||||||||||||||||||||
Expected return on plan assets (a) | ( | ( | ( | ( | ||||||||||||||||||||||
Amortization of prior service credit (a) | ( | |||||||||||||||||||||||||
Amortization of net loss (a) | ||||||||||||||||||||||||||
| Net periodic benefit cost | ||||||||||||||||||||||||||
| Effects of regulation | ||||||||||||||||||||||||||
| Net benefit cost recognized for financial reporting | $ | $ | $ | $ | ||||||||||||||||||||||
| Six Months Ended June 30 | ||||||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||||||
| (Millions of Dollars) | Pension Benefits | Postretirement Health Care Benefits | ||||||||||||||||||||||||
| Service cost | $ | $ | $ | $ | ||||||||||||||||||||||
Interest cost (a) | ||||||||||||||||||||||||||
Expected return on plan assets (a) | ( | ( | ( | ( | ||||||||||||||||||||||
Amortization of prior service credit (a) | ( | |||||||||||||||||||||||||
Amortization of net loss (a) | ||||||||||||||||||||||||||
| Net periodic benefit cost | ||||||||||||||||||||||||||
| Effects of regulation | ( | |||||||||||||||||||||||||
| Net benefit cost recognized for financial reporting | $ | $ | $ | $ | ||||||||||||||||||||||
(a)The components of net periodic cost other than the service cost component are included in the line item “Other income, net” in the consolidated statements of income or capitalized on the consolidated balance sheets as a regulatory asset.
10. Commitments and Contingencies | ||
Legal
Xcel Energy is involved in various litigation matters in the ordinary course of business. The assessment of whether a loss is probable or is a reasonable possibility, and whether the loss or a range of loss is estimable, often involves a series of complex judgments about future events. Management maintains accruals for losses probable of being incurred and subject to reasonable estimation.
Management is sometimes unable to estimate an amount or range of a reasonably possible loss in certain situations, including but not limited to when (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories.
In such cases, there is considerable uncertainty regarding the timing or ultimate resolution, including a possible eventual loss. For current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, would have a material effect on Xcel Energy’s consolidated financial statements. Legal fees are generally expensed as incurred.
19
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.
After reaching the generally applicable two-year statute of limitations for property damage in Texas, SPS is aware of approximately 73 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 73 complaints, 28 have been resolved.
SPS has received 304 claims through its claims process, net of duplicative, withdrawn and denied claims, and has reached final settlements on 237 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 107 additional claims and has reached settlement of 79 of those claims through mediation.
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. In February 2026, pending resolution of the lawsuit, SPS and the Texas Attorney General’s office jointly filed a temporary injunction agreeing to certain distribution pole replacement procedures, largely consistent with current procedures.
SPS has settled claims related to both 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 $404 million of expected loss payments, of which $398 million and $374 million were paid through June 30, 2026 and Dec. 31, 2025, respectively.
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 $56 million of remaining estimated probable losses for the matter (before available insurance), for a total estimated loss of $460 million. Additionally, approximately $43 million in legal costs have been incurred as of June 30, 2026, resulting in total estimated losses and incurred costs related to this proceeding of $503 million as of June 30, 2026. An estimated liability of $62 million and $56 million for estimated losses is presented in other current liabilities as of June 30, 2026 and Dec. 31, 2025, respectively.
The estimated remaining probable losses for complaints and claims in connection with the Smokehouse Creek Fire Complex (before available insurance) represents the low end of the range for remaining reasonably estimable losses and is subject to change as additional information becomes available. This 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 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 the nature of demands that may be made. Resolution of remaining complaints and claims associated with the Smokehouse Creek Fire Complex could exceed our insurance coverage of $525 million for the annual policy period (of which approximately $80 million of coverage remains after consideration of settlements reached and legal costs incurred through June 30, 2026) 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 $81 million and $195 million, net of recoveries received are presented in prepayments and other current assets as of June 30, 2026 and Dec. 31, 2025, 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.
Marshall Wildfire Litigation — In December 2021, a wildfire occurred in Boulder County, Colorado (Marshall Fire). According to a 2023 report of the Boulder County Sheriff, on Dec. 30, 2021, a fire ignited on a residential property in Boulder, Colorado for reasons unrelated to PSCo’s power lines. Also according to the 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, approximately 80 to 110 feet away from PSCo’s power lines in the area.
20
PSCo received complaints alleging that PSCo’s equipment ignited the Marshall Fire and asserted various causes of action under Colorado law. In addition to asserting claims against PSCo and certain of its affiliates, various plaintiffs asserted claims against certain telecommunications companies.
In September 2025, Xcel Energy and other defendants reached settlement agreements in principle that resolved all claims and required PSCo to make settlement payments of $640 million. PSCo did not admit any fault, wrongdoing or negligence in connection with these settlement agreements. As of July 2026, settlements have been executed with all plaintiffs and subrogation insurers.
As a result of settlements as well as legal and other costs of the matter, PSCo recognized charges to earnings of $298 million in the year ended Dec. 31, 2025, after consideration of total costs expected to be reimbursed by insurance. In 2026, PSCo increased its estimated amount recoverable from insurance, contributing to a net $19 million credit to earnings for the six months ended June 30, 2026.
Rate Matters and Other
Xcel Energy’s operating subsidiaries are involved in various regulatory proceedings arising in the ordinary course of business. Until resolution, typically in the form of a rate order, uncertainties may exist regarding the ultimate rate treatment for certain activities and transactions. Amounts have been recognized for probable and reasonably estimable losses that may result. Unless otherwise disclosed, any reasonably possible range of loss in excess of any recognized amount is not expected to have a material effect on the consolidated financial statements.
Prairie Island Outage Prudency Review — In March 2024, NSP-Minnesota filed its annual fuel clause adjustment true-up petition to the MPUC. In a response to that petition, intervenors recommended refunds for replacement power costs related to an outage at the Prairie Island generating station (October 2023 through February 2024).
In a September 2024 decision, the MPUC ruled NSP-Minnesota was imprudent in the operation of the Prairie Island nuclear plant based on an incident that resulted in the extended outage. The MPUC did not quantify the refund and referred the determination of the refund amount to the Office of Administrative Hearings. NSP-Minnesota recorded an estimated liability for a customer refund in 2024.
In March 2026, the ALJ recommended a $41 million disallowance of estimated replacement power costs. In May 2026, the MPUC ordered a $41 million disallowance, consistent with the ALJ recommendation. NSP-Minnesota recognized an incremental $37 million in customer refunds, including interest, to electric revenues in the first quarter of 2026. Incremental interest was recognized in the second quarter of 2026.
Environmental
New and changing federal and state environmental mandates can create financial liabilities for Xcel Energy, which are normally recovered through the regulated rate process.
Site Remediation
Various federal and state environmental laws impose liability where hazardous substances or other regulated materials have been released to the environment. Xcel Energy Inc.’s subsidiaries may sometimes pay all or a portion of the cost to remediate sites where past activities of their predecessors or other parties have caused environmental contamination.
Environmental contingencies could arise from various situations, including sites of former MGPs; and third-party sites, such as landfills, for which one or more of Xcel Energy Inc.’s subsidiaries are alleged to have sent wastes to that site.
MGP, Landfill and Disposal Sites
Xcel Energy is investigating, remediating or performing post-closure actions at 15 historical MGP, landfill or other disposal sites across its service territories, excluding sites that are being addressed under current coal ash regulations (see below).
Xcel Energy has approximately $15 million of remaining liabilities for resolution of these issues, however, the final outcome and timing are unknown. In addition, there may be regulatory recovery, insurance recovery and/or recovery from other potentially responsible parties, offsetting a portion of costs incurred.
Water and Waste
Coal Ash Regulation — Xcel Energy is subject to the CCR Rule, which imposes requirements for handling, storage, treatment and disposal of coal ash and other solid waste.
In May 2024, final amendments to the CCR Rule were published, widening its scope to include legacy CCR surface impoundments at inactive facilities and previously exempt areas where CCR was placed directly on land at CCR-regulated facilities, including areas of beneficial use.
As a requirement of the CCR Rule, utilities must complete facility evaluations and groundwater sampling around their subject landfills, surface impoundments and certain other areas where coal ash was placed on land.
If certain impacts to groundwater are detected, utilities are required to perform additional groundwater investigations and/or perform corrective actions.
Xcel Energy continues to perform site investigation activities related to the CCR Rule, which may result in updates to estimated costs as well as identification of additional required corrective actions.
In February 2026, the EPA issued a final rule amending the CCR Legacy rule. The ruling extends deadlines for various regulatory actions and clarifies previous information regarding implementation of the rule. Xcel Energy anticipates impacts to be consistent with prior accruals.
In April 2026, the EPA published a new proposed rule with additional amendments to the CCR Legacy Rule. Xcel Energy is evaluating this proposed rule and its potential impacts.
Air
Clean Air Act NOx Allowance Allocations — In June 2023, the EPA published final regulations for ozone under the “Good Neighbor” provisions of the Clean Air Act that established NOx allowance budgets for fossil fuel-fired electric generating facilities in subject states. The final rule establishes a federal plan and applies to generation facilities in Minnesota, Texas, and Wisconsin, as well as other states outside of our service territory. The EPA later proposed to include New Mexico in the federal plan.
If the rule is implemented, Xcel Energy anticipates the annual costs could be significant but recoverable through regulatory mechanisms. However, the plan is subject to both judicial and administrative stays while the EPA reconsiders the rule. In January 2026, the EPA proposed Phase 1 of its reconsideration of the “Good Neighbor” rule. Xcel Energy will continue to evaluate any additional phases of the reconsideration of this rule as they are published by the EPA.
21
Leases
Finance lease payments are allocated between interest charges and depreciation and amortization on the consolidated statements of income. PPA operating lease payments are included in electric fuel and purchased power, and expense for other operating leases is included in O&M expense and electric fuel and purchased power.
Components of lease expense:
| Three Months Ended June 30 | ||||||||||||||
| (Millions of Dollars) | 2026 | 2025 | ||||||||||||
| Operating leases | ||||||||||||||
| PPA capacity payments | $ | $ | ||||||||||||
Other operating leases (a) | ||||||||||||||
| Total operating lease expense | $ | $ | ||||||||||||
| Finance leases | ||||||||||||||
| Amortization of ROU assets | $ | $ | ||||||||||||
| Interest expense on lease liability | ||||||||||||||
| Total finance lease expense | $ | $ | ||||||||||||
| Six Months Ended June 30 | ||||||||||||||
| (Millions of Dollars) | 2026 | 2025 | ||||||||||||
| Operating leases | ||||||||||||||
| PPA capacity payments | $ | $ | ||||||||||||
Other operating leases (a) | ||||||||||||||
| Total operating lease expense | $ | $ | ||||||||||||
| Finance leases | ||||||||||||||
| Amortization of ROU assets | $ | $ | ||||||||||||
| Interest expense on lease liability | ||||||||||||||
| Total finance lease expense | $ | $ | ||||||||||||
(a)Includes immaterial short-term lease expense.
Commitments under operating and finance leases as of June 30, 2026:
| (Millions of Dollars) | PPA Operating Leases | Other Operating Leases | Total Operating Leases | Finance Leases (a) | ||||||||||||||||||||||
| Total minimum obligation | $ | $ | $ | $ | ||||||||||||||||||||||
| Interest component of obligation | ( | ( | ( | ( | ||||||||||||||||||||||
| Present value of minimum obligation | $ | $ | ||||||||||||||||||||||||
| Less current portion | ( | ( | ||||||||||||||||||||||||
| Noncurrent operating and finance lease liabilities | $ | $ | ||||||||||||||||||||||||
(a)Excludes certain amounts related to PSCo’s lease obligations given Xcel Energy’s 50 % ownership interest in WYCO.
Variable Interest Entities
Under certain PPAs, NSP-Minnesota, PSCo and SPS purchase power from IPPs for which the utility subsidiaries are required to reimburse fuel costs, or to participate in tolling arrangements under which the utility subsidiaries procure the natural gas required to produce the energy that they purchase. Xcel Energy has determined that certain IPPs are VIEs, however Xcel Energy is not directly subject to risk of loss from the operations of these entities, and no additional significant financial support is required other than contractual payments for energy and capacity.
In addition, certain solar PPAs provide an option to purchase emission allowances or sharing provisions for specified transactions. These specific PPAs create a variable interest in the IPP.
Xcel Energy evaluated each of these VIEs for possible consolidation and concluded that these entities are not required to be consolidated in its consolidated financial statements because Xcel Energy does not have the power to direct the activities that most significantly impact the entities’ economic performance.
The utility subsidiaries had 3,476
Other
Guarantees and Bond Indemnifications — Xcel Energy Inc. and its subsidiaries provide guarantees and bond indemnities, which guarantee payment or performance. Xcel Energy Inc.’s exposure is based upon the net liability under the specified agreements or transactions. Most of the guarantees and bond indemnities issued by Xcel Energy Inc. and its subsidiaries have a stated maximum amount.
As of June 30, 2026 and Dec. 31, 2025, Xcel Energy had no 135 million and $120 million at June 30, 2026 and Dec. 31, 2025, respectively.
Other Indemnification Agreements — Xcel Energy Inc. and its subsidiaries provide indemnifications through various contracts. These are primarily indemnifications against adverse litigation outcomes in connection with underwriting agreements, breaches of representations and warranties, including corporate existence, transaction authorization and income tax matters with respect to assets sold, as well as disallowances or reductions to the contractual amounts of tax credit transfers.
Xcel Energy Inc.’s and its subsidiaries’ obligations under these agreements may be limited in terms of duration and amount. Maximum future payments under these indemnifications cannot be reasonably estimated as the dollar amounts are often not explicitly stated.
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11. Other Comprehensive Loss | ||
Changes in accumulated other comprehensive loss, net of tax:
| Three Months Ended June 30, 2026 | Three Months Ended June 30, 2025 | |||||||||||||||||||||||||||||||||||||
| (Millions of Dollars) | Gains and Losses on Cash Flow Hedges | Defined Benefit Pension and Postretirement Items | Total | Gains and Losses on Cash Flow Hedges | Defined Benefit Pension and Postretirement Items | Total | ||||||||||||||||||||||||||||||||
| Accumulated other comprehensive loss at April 1 | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | ||||||||||||||||||||||||||
Other comprehensive gain before reclassifications | ||||||||||||||||||||||||||||||||||||||
| Losses reclassified from net accumulated other comprehensive loss: | ||||||||||||||||||||||||||||||||||||||
Interest rate derivatives (a) | ||||||||||||||||||||||||||||||||||||||
Amortization of net actuarial losses (b) | ||||||||||||||||||||||||||||||||||||||
| Net current period other comprehensive income | ||||||||||||||||||||||||||||||||||||||
| Accumulated other comprehensive loss at June 30 | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | ||||||||||||||||||||||||||
| Six Months Ended June 30, 2026 | Six Months Ended June 30, 2025 | |||||||||||||||||||||||||||||||||||||
| (Millions of Dollars) | Gains and Losses on Cash Flow Hedges | Defined Benefit Pension and Postretirement Items | Total | Gains and Losses on Cash Flow Hedges | Defined Benefit Pension and Postretirement Items | Total | ||||||||||||||||||||||||||||||||
| Accumulated other comprehensive loss at Jan. 1 | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | ||||||||||||||||||||||||||
| Other comprehensive gain before reclassifications | ||||||||||||||||||||||||||||||||||||||
| Losses reclassified from net accumulated other comprehensive loss: | ||||||||||||||||||||||||||||||||||||||
Interest rate derivatives (a) | ||||||||||||||||||||||||||||||||||||||
Amortization of net actuarial losses (b) | ||||||||||||||||||||||||||||||||||||||
| Net current period other comprehensive income | ||||||||||||||||||||||||||||||||||||||
| Accumulated other comprehensive loss at June 30 | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | ||||||||||||||||||||||||||
(a)Included in interest charges.
(b)Included in the computation of net periodic pension and postretirement benefit costs. See Note 9 for further information .
12. Segment Information | ||||||||||||||
Segment information and reconciliation to Xcel Energy’s consolidated net income:
| Three Months Ended June 30, 2026 | ||||||||||||||||||||
| (Millions of Dollars) | Regulated electric utility | Regulated natural gas utility | Total segments | |||||||||||||||||
| Operating revenues | $ | $ | $ | |||||||||||||||||
| Intersegment revenue | ||||||||||||||||||||
| Total segment revenues | ||||||||||||||||||||
| Electric fuel and purchased power | ||||||||||||||||||||
| Cost of natural gas sold and transported | ||||||||||||||||||||
| O&M expenses | ||||||||||||||||||||
| Depreciation and amortization | ||||||||||||||||||||
| Other segment expenses, net | ||||||||||||||||||||
| Interest charges and financing costs | ||||||||||||||||||||
| Income tax benefit | ( | ( | ( | |||||||||||||||||
| Net income | $ | $ | $ | |||||||||||||||||
| Total segment net income | $ | |||||||||||||||||||
| Non-segment net loss | ( | |||||||||||||||||||
| Consolidated net income | $ | |||||||||||||||||||
| Three Months Ended June 30, 2025 | ||||||||||||||||||||
| (Millions of Dollars) | Regulated electric utility | Regulated natural gas utility | Total segments | |||||||||||||||||
| Operating revenues | $ | $ | $ | |||||||||||||||||
| Intersegment revenue | ||||||||||||||||||||
| Total segment revenues | ||||||||||||||||||||
| Electric fuel and purchased power | ||||||||||||||||||||
| Cost of natural gas sold and transported | ||||||||||||||||||||
| O&M expenses | ||||||||||||||||||||
| Depreciation and amortization | ||||||||||||||||||||
| Other segment expenses, net | ||||||||||||||||||||
| Interest charges and financing costs | ||||||||||||||||||||
| Income tax benefit | ( | ( | ( | |||||||||||||||||
| Net income | $ | $ | $ | |||||||||||||||||
| Total segment net income | $ | |||||||||||||||||||
| Non-segment net loss | ( | |||||||||||||||||||
| Consolidated net income | $ | |||||||||||||||||||
23
| Six Months Ended June 30, 2026 | ||||||||||||||||||||
| (Millions of Dollars) | Regulated electric utility | Regulated natural gas utility | Total segments | |||||||||||||||||
| Operating revenues | $ | $ | $ | |||||||||||||||||
| Intersegment revenue | ||||||||||||||||||||
| Total segment revenues | ||||||||||||||||||||
| Electric fuel and purchased power | ||||||||||||||||||||
| Cost of natural gas sold and transported | ||||||||||||||||||||
| O&M expenses | ||||||||||||||||||||
| Depreciation and amortization | ||||||||||||||||||||
| Other segment expenses, net | ||||||||||||||||||||
| Interest charges and financing costs | ||||||||||||||||||||
| Income tax (benefit) expense | ( | ( | ||||||||||||||||||
| Net income | $ | $ | $ | |||||||||||||||||
| Total segment net income | $ | |||||||||||||||||||
| Non-segment net loss | ( | |||||||||||||||||||
| Consolidated net income | $ | |||||||||||||||||||
| Six Months Ended June 30, 2025 | ||||||||||||||||||||
| (Millions of Dollars) | Regulated electric utility | Regulated natural gas utility | Total segments | |||||||||||||||||
| Operating revenues | $ | $ | $ | |||||||||||||||||
| Intersegment revenue | ||||||||||||||||||||
| Total segment revenues | ||||||||||||||||||||
| Electric fuel and purchased power | ||||||||||||||||||||
| Cost of natural gas sold and transported | ||||||||||||||||||||
| O&M expenses | ||||||||||||||||||||
| Depreciation and amortization | ||||||||||||||||||||
| Other segment expenses, net | ||||||||||||||||||||
| Interest charges and financing costs | ||||||||||||||||||||
| Income tax (benefit) expense | ( | ( | ||||||||||||||||||
| Net income | $ | $ | $ | |||||||||||||||||
| Total segment net income | $ | |||||||||||||||||||
| Non-segment net loss | ( | |||||||||||||||||||
| Consolidated net income | $ | |||||||||||||||||||
Equity method investments in the regulated natural gas utility segment of $69 million and $81 million at June 30, 2026 and Dec. 31, 2025, respectively, primarily relate to WYCO. Non-segment equity method investments of $252 million and $204 million as of June 30, 2026 and Dec. 31, 2025, respectively, relate to investments in energy technology funds.
Asset and capital expenditure information is not provided for Xcel Energy’s reportable segments. As an integrated electric and natural gas utility, Xcel Energy operates significant assets that are not dedicated to a specific business segment.
Reporting assets and capital expenditures by business segment would require arbitrary and potentially misleading allocations, which may not necessarily reflect the assets that would be required for the operation of the business segments on a stand-alone basis.
Certain costs, such as common depreciation, common O&M expenses and interest expense are allocated based on cost causation allocators across each segment. In addition, a general allocator is used for certain general and administrative expenses, including office supplies, rent, property insurance and general advertising.
ITEM 2 — MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS | ||||||||||||||
The following discussion and analysis by management focuses on those factors that had a material effect on Xcel Energy’s financial condition, results of operations and cash flows during the periods presented or are expected to have a material impact in the future. It should be read in conjunction with the accompanying unaudited consolidated financial statements and the related notes to consolidated financial statements. Due to the seasonality of Xcel Energy’s operating results, quarterly financial results are not an appropriate base from which to project annual results.
The demand for electric power and natural gas is affected by seasonal differences in the weather. In general, peak sales of electricity occur in the summer months, and peak sales of natural gas occur in the winter months. As a result, the overall operating results may fluctuate substantially on a seasonal basis. Additionally, Xcel Energy’s operations have historically generated less revenues and income when weather conditions are milder in the winter and cooler in the summer.
Non-GAAP Financial Measures
The following discussion includes financial information prepared in accordance with GAAP, as well as certain non-GAAP financial measures such as 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 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.
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.
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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 EPS, 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.
The following table provides a reconciliation of GAAP earnings (net income) to ongoing earnings:
| Three Months Ended June 30 | Six Months Ended June 30 | |||||||||||||||||||||||||
| (Millions of Dollars) | 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||||
| GAAP net income | $ | 586 | $ | 444 | $ | 1,142 | $ | 927 | ||||||||||||||||||
| Prairie Island outage refunds | 1 | — | 38 | — | ||||||||||||||||||||||
| Marshall Wildfire litigation | 3 | — | (19) | — | ||||||||||||||||||||||
| Tax effect | (1) | — | (5) | — | ||||||||||||||||||||||
| Ongoing earnings | $ | 589 | $ | 444 | $ | 1,156 | $ | 927 | ||||||||||||||||||
Prairie Island Outage Refunds — In March 2026, the ALJ recommended a disallowance of $41 million for estimated replacement power costs incurred during a 2023-2024 outage at NSP-Minnesota’s Prairie Island nuclear facility. The MPUC ordered the ALJ-recommended disallowance in May 2026. Total non-recurring charges of $38 million were recorded to electric revenues during the six months ended June 30, 2026 for incremental customer refunds, including interest.
Marshall Wildfire Litigation — In the six months ended June 30, 2026, PSCo recognized $19 million of net reductions to operating expenses due primarily to an increase in the estimated amount recoverable from insurance for non-recurring Marshall Wildfire costs.
| Results of Operations | ||
The only common equity securities that are publicly traded are common shares of Xcel Energy Inc. Diluted earnings and EPS of each subsidiary discussed below do not represent a direct legal interest in the assets and liabilities allocated to such subsidiary but rather represent a direct interest in our assets and liabilities as a whole.
Xcel Energy’s second quarter diluted GAAP and ongoing earnings were $0.93 per share compared with $0.75 per share in the same period in 2025. The change in earnings per share was primarily driven by increased recovery of electric infrastructure investments, partially offset by higher financing costs. 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).
Summarized diluted EPS for Xcel Energy:
| Three Months Ended June 30 | Six Months Ended June 30 | |||||||||||||||||||||||||
| Diluted Earnings (Loss) Per Share | 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||||
| PSCo | $ | 0.32 | $ | 0.26 | $ | 0.74 | $ | 0.71 | ||||||||||||||||||
| NSP-Minnesota | 0.37 | 0.32 | 0.67 | 0.64 | ||||||||||||||||||||||
| SPS | 0.19 | 0.17 | 0.33 | 0.27 | ||||||||||||||||||||||
| NSP-Wisconsin | 0.06 | 0.05 | 0.17 | 0.12 | ||||||||||||||||||||||
| Earnings from equity method investments — WYCO | 0.01 | 0.01 | 0.02 | 0.02 | ||||||||||||||||||||||
Regulated utility (a) | 0.95 | 0.81 | 1.92 | 1.76 | ||||||||||||||||||||||
| Xcel Energy Inc. and Other | (0.02) | (0.06) | (0.10) | (0.17) | ||||||||||||||||||||||
GAAP diluted EPS (a) | $ | 0.93 | $ | 0.75 | $ | 1.82 | $ | 1.59 | ||||||||||||||||||
| Prairie Island outage refunds | — | — | 0.04 | — | ||||||||||||||||||||||
| Marshall Wildfire litigation | — | — | (0.02) | — | ||||||||||||||||||||||
Ongoing diluted EPS (a) | $ | 0.93 | $ | 0.75 | $ | 1.84 | $ | 1.59 | ||||||||||||||||||
(a)Amounts may not add due to rounding.
Summary of Earnings
PSCo — GAAP and ongoing earnings increased $0.06 per share for the second quarter of 2026. Year-to-date GAAP earnings increased $0.03 per share and ongoing earnings increased $0.01 per share. The increase in year-to-date ongoing earnings was driven by higher recovery of electric infrastructure investments which was partially offset by unfavorable weather. The difference between GAAP and ongoing earnings was driven by an increase in the estimated amount recoverable from insurance for Marshall Wildfire costs.
NSP-Minnesota — GAAP and ongoing earnings increased $0.05 per share for the second quarter of 2026. Year-to-date GAAP earnings increased $0.03 per share and ongoing earnings increased $0.07 per share. The year-to-date ongoing earnings increase was driven by higher recovery of electric and natural gas infrastructure investments, which was partially offset by increased interest charges. The difference between GAAP and ongoing earnings was driven by recognition of customer refunds related to the 2023-2024 Prairie Island nuclear facility outage.
SPS — GAAP and ongoing earnings increased $0.02 per share for the second quarter and $0.06 per share year-to-date. The year-to-date change was driven by sales growth and higher recovery of electric infrastructure investments, partially offset by increased depreciation expense.
NSP-Wisconsin — GAAP and ongoing earnings increased $0.01 per share for the second quarter and $0.05 year-to-date. The year-to-date change was driven by higher recovery of electric and natural gas infrastructure investments, partially offset by increased depreciation expense and interest charges.
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 increase in earnings was largely due to unrealized gains on the investment funds’ interests in energy technology companies, partially offset by higher debt levels.
25
Changes in GAAP and Ongoing EPS
Components significantly contributing to changes in 2026 EPS compared to 2025:
| Diluted Earnings (Loss) Per Share | Three Months Ended June 30 | Six Months Ended June 30 | ||||||||||||
| GAAP EPS — 2025 | $ | 0.75 | $ | 1.59 | ||||||||||
| Components of change - 2026 vs. 2025 | ||||||||||||||
| Lower electric fuel and purchased power | 0.30 | 0.31 | ||||||||||||
| Higher AFUDC equity & debt | 0.08 | 0.18 | ||||||||||||
| Lower depreciation and amortization | 0.08 | 0.03 | ||||||||||||
| Marshall Wildfire litigation | — | 0.02 | ||||||||||||
| (Lower) higher electric revenues | (0.18) | — | ||||||||||||
| Higher interest charges | (0.12) | (0.22) | ||||||||||||
| Common equity financing | (0.06) | (0.14) | ||||||||||||
| Lower natural gas revenues | (0.04) | (0.07) | ||||||||||||
| Other, net | 0.12 | 0.12 | ||||||||||||
| GAAP EPS — 2026 | $ | 0.93 | $ | 1.82 | ||||||||||
| Prairie Island outage refunds | — | 0.04 | ||||||||||||
| Marshall Wildfire litigation | — | (0.02) | ||||||||||||
Ongoing EPS — 2026 | $ | 0.93 | $ | 1.84 | ||||||||||
Statement of Income Analysis
The following summarizes the items that affected the individual revenue and expense items reported in the consolidated statements of income.
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.
Degree-day or THI data is used to estimate amounts of energy required to maintain comfortable indoor temperature levels based on each day’s average temperature and humidity. HDD is the measure of the variation in the weather based on the extent to which the average daily temperature falls below 65° Fahrenheit. CDD is the measure of the variation in the weather based on the extent to which the average daily temperature rises above 65° Fahrenheit.
Each degree of temperature above 65° Fahrenheit is counted as one CDD, and each degree of temperature below 65° Fahrenheit is counted as one HDD. In Xcel Energy’s more humid service territories, a THI is used in place of CDD, which adds a humidity factor to CDD. HDD, CDD and THI are most likely to impact the usage of Xcel Energy’s residential and commercial customers. Industrial customers are less sensitive to weather. Typically, sales are not impacted in the first or fourth quarter due to THI or CDD.
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.
Percentage increase (decrease) in normal and actual HDD, CDD and THI:
| Three Months Ended June 30 | Six Months Ended June 30 | ||||||||||||||||||||||||||||||||||
| 2026 vs. Normal | 2025 vs. Normal | 2026 vs. 2025 | 2026 vs. Normal | 2025 vs. Normal | 2026 vs. 2025 | ||||||||||||||||||||||||||||||
| HDD | (12.3) | % | (7.1) | % | (6.2) | % | (14.7) | % | (1.3) | % | (13.7) | % | |||||||||||||||||||||||
| CDD | 14.7 | (6.7) | 24.6 | 22.9 | (5.9) | 33.5 | |||||||||||||||||||||||||||||
| THI | (1.9) | (7.1) | 4.4 | (2.1) | (7.3) | 4.4 | |||||||||||||||||||||||||||||
Weather — Estimated impact of temperature variations on EPS compared with normal weather conditions:
| Three Months Ended June 30 | Six Months Ended June 30 | ||||||||||||||||||||||||||||||||||
| 2026 vs. Normal | 2025 vs. Normal | 2026 vs. 2025 | 2026 vs. Normal | 2025 vs. Normal | 2026 vs. 2025 | ||||||||||||||||||||||||||||||
| Retail electric | $ | 0.001 | $ | (0.013) | $ | 0.014 | $ | (0.030) | $ | (0.007) | $ | (0.023) | |||||||||||||||||||||||
Sales true-up | 0.001 | — | 0.001 | 0.008 | — | 0.008 | |||||||||||||||||||||||||||||
| Electric total | $ | 0.002 | $ | (0.013) | $ | 0.015 | $ | (0.022) | $ | (0.007) | $ | (0.015) | |||||||||||||||||||||||
| Firm natural gas | (0.008) | (0.005) | (0.003) | (0.088) | 0.001 | (0.089) | |||||||||||||||||||||||||||||
| Decoupling | 0.001 | 0.001 | — | 0.009 | 0.002 | 0.007 | |||||||||||||||||||||||||||||
| Natural gas total | $ | (0.007) | $ | (0.004) | $ | (0.003) | $ | (0.079) | $ | 0.003 | $ | (0.082) | |||||||||||||||||||||||
| Total | $ | (0.005) | $ | (0.017) | $ | 0.012 | $ | (0.101) | $ | (0.004) | $ | (0.097) | |||||||||||||||||||||||
Sales — Sales growth (decline) for actual and weather-normalized sales volumes in 2026 compared to 2025:
| Three Months Ended June 30 | ||||||||||||||||||||||||||||||||
| PSCo | NSP-Minnesota | SPS | NSP-Wisconsin | Xcel Energy | ||||||||||||||||||||||||||||
| Actual | ||||||||||||||||||||||||||||||||
| Electric residential | 2.1 | % | 1.9 | % | 6.3 | % | (1.2) | % | 2.4 | % | ||||||||||||||||||||||
| Electric C&I | (0.2) | 2.8 | 2.9 | 2.7 | 2.0 | |||||||||||||||||||||||||||
| Total retail electric sales | 0.5 | 2.5 | 3.3 | 1.6 | 2.1 | |||||||||||||||||||||||||||
| Firm natural gas sales | (10.9) | (1.4) | N/A | (10.2) | (7.8) | |||||||||||||||||||||||||||
| Three Months Ended June 30 | ||||||||||||||||||||||||||||||||
| PSCo | NSP-Minnesota | SPS | NSP-Wisconsin | Xcel Energy | ||||||||||||||||||||||||||||
| Weather-Normalized | ||||||||||||||||||||||||||||||||
| Electric residential | 1.8 | % | 0.4 | % | (0.1) | % | 2.3 | % | 1.0 | % | ||||||||||||||||||||||
| Electric C&I | (0.3) | 2.7 | 2.1 | 3.4 | 1.7 | |||||||||||||||||||||||||||
| Total retail electric sales | 0.3 | 1.9 | 1.7 | 3.0 | 1.5 | |||||||||||||||||||||||||||
| Firm natural gas sales | (9.1) | (2.5) | N/A | (6.9) | (6.9) | |||||||||||||||||||||||||||
26
| Six Months Ended June 30 | ||||||||||||||||||||||||||||||||
| PSCo | NSP-Minnesota | SPS | NSP-Wisconsin | Xcel Energy | ||||||||||||||||||||||||||||
| Actual | ||||||||||||||||||||||||||||||||
| Electric residential | (3.1) | % | 1.0 | % | (4.3) | % | (0.4) | % | (1.4) | % | ||||||||||||||||||||||
| Electric C&I | (0.7) | 2.3 | 6.6 | 1.5 | 2.8 | |||||||||||||||||||||||||||
| Total retail electric sales | (1.5) | 1.9 | 5.0 | 0.9 | 1.6 | |||||||||||||||||||||||||||
| Firm natural gas sales | (21.8) | (3.4) | N/A | (5.0) | (14.7) | |||||||||||||||||||||||||||
| Six Months Ended June 30 | ||||||||||||||||||||||||||||||||
| PSCo | NSP-Minnesota | SPS | NSP-Wisconsin | Xcel Energy | ||||||||||||||||||||||||||||
| Weather-Normalized | ||||||||||||||||||||||||||||||||
| Electric residential | (0.1) | % | 1.1 | % | (2.9) | % | 1.7 | % | 0.1 | % | ||||||||||||||||||||||
| Electric C&I | — | 2.4 | 6.2 | 1.9 | 3.0 | |||||||||||||||||||||||||||
| Total retail electric sales | (0.1) | 2.0 | 4.8 | 1.8 | 2.1 | |||||||||||||||||||||||||||
| Firm natural gas sales | (2.5) | 0.3 | N/A | (1.9) | (1.5) | |||||||||||||||||||||||||||
Weather-normalized electric sales growth (decline) — year-to-date
•C&I sales — Increase is due to higher use per customer in SPS (6.0%) and NSP-Minnesota (2.0%) and customer growth in NSP-Wisconsin (1.0%). Increased activity in the energy sector in SPS and the manufacturing sector in all jurisdictions contributed to the sales growth.
Weather-normalized natural gas sales growth (decline) — year-to-date
•Decrease in natural gas sales was driven primarily by reduced use per customer in most jurisdictions and customer classes.
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, which reduce electric revenue and income taxes.
| (Millions of Dollars) | Three Months Ended June 30, 2026 vs. 2025 | Six Months Ended June 30, 2026 vs. 2025 | ||||||||||||
| Non-fuel riders | $ | 114 | $ | 203 | ||||||||||
| Sales and demand | 25 | 69 | ||||||||||||
| Wholesale transmission | 29 | 44 | ||||||||||||
| Conservation and demand side management (offset in expense) | 21 | 41 | ||||||||||||
| Recovery of lower cost of electric fuel and purchased power | (202) | (169) | ||||||||||||
| PTCs flowed back to customers (offset in ETR) | (41) | (59) | ||||||||||||
| Wholesale generation | (32) | (44) | ||||||||||||
| Prairie Island outage refunds | (1) | (38) | ||||||||||||
Regulatory rate outcomes (MN, WI and SD) (a) | (36) | (20) | ||||||||||||
| Estimated impact of weather | 12 | (11) | ||||||||||||
| Other, net | (27) | (13) | ||||||||||||
| Total (decrease) increase | $ | (138) | $ | 3 | ||||||||||
(a)Decrease primarily due to recognition of interim rate refunds in the Minnesota Electric Rate Case. Reduced electric revenue was more than offset by corresponding reductions in depreciation expense due to nuclear life extensions approved in the case.
Natural Gas Revenues
Natural gas revenues vary with changing sales, the cost of natural gas and regulatory outcomes.
| (Millions of Dollars) | Three Months Ended June 30, 2026 vs. 2025 | Six Months Ended June 30, 2026 vs. 2025 | ||||||||||||
| Estimated impact of weather (net of decoupling) | $ | (1) | $ | (62) | ||||||||||
| Recovery of lower cost of natural gas | (40) | (36) | ||||||||||||
| Regulatory rate outcomes (MN and WI) | 9 | 37 | ||||||||||||
| Other, net | 1 | 5 | ||||||||||||
| Total decrease | $ | (31) | $ | (56) | ||||||||||
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 decreased $240 million for the second quarter of 2026 and $241 million year-to-date. The year-to-date change was primarily due to lower commodity prices, largely in SPS..
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 decreased $41 million for the second quarter of 2026 and $34 million year-to-date. The year-to-date change was primarily due to decreased volumes in PSCo, partially offset by higher commodity prices.
Non-Fuel Operating Expenses and Other Items
O&M Expenses — O&M expenses increased $16 million for the second quarter of 2026 and $5 million year-to-date. The year-to-date change was primarily due to increased generation costs.
Depreciation and Amortization — Depreciation and amortization decreased $60 million for the second quarter of 2026 and $20 million year-to-date. The year-to-date change was primarily due to the recognition of 2025 and 2026 depreciation reductions (nuclear life extensions) in the second quarter of 2026, partially offset by system expansion.
Interest Charges — Interest charges increased $94 million for the second quarter of 2026 and $174 million year-to-date. The year-to-date change was primarily due to higher debt levels.
Earnings from Equity Method Investments — Earnings from equity method investments increased $84 million for the second quarter of 2026 and $98 million year-to-date. The year-to-date change was primarily due to unrealized gains on investment funds’ interests in energy technology companies in the first six months of 2026 and losses in the first six months of 2025.
AFUDC, Equity and Debt — AFUDC increased $54 million for the second quarter of 2026 and $115 million year-to-date. The year-to-date change was primarily due to system investment.
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| Public Utility Regulation and Other | ||
The FERC and various state and local regulatory commissions regulate Xcel Energy Inc.’s utility subsidiaries and West Gas Interstate. Xcel Energy is subject to rate regulation by state utility regulatory agencies, which have jurisdiction with respect to the rates of electric and natural gas distribution companies in Minnesota, North Dakota, South Dakota, Wisconsin, Michigan, Colorado, New Mexico and Texas.
Rates are designed to recover plant investment, operating costs and an allowed return on investment. Our utility subsidiaries request changes in utility rates through commission filings. Changes in operating costs can affect Xcel Energy’s financial results, depending on the timing of rate cases and implementation of final rates. Other factors affecting rate filings are new investments, sales, conservation and demand side management efforts and the cost of capital.
In addition, the regulatory commissions authorize the ROE, capital structure and depreciation rates in rate proceedings. Decisions by these regulators can significantly impact Xcel Energy’s results of operations.
Except to the extent noted below, the circumstances set forth in Public Utility Regulation included in Item 7 of Xcel Energy’s Annual Report on Form 10-K for the year ended Dec. 31, 2025 appropriately represent, in all material respects, the current status of public utility regulation and are incorporated herein by reference.
NSP-Minnesota
Pending and Recently Concluded Regulatory Proceedings
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 October 2025, NSP-Minnesota filed rebuttal testimony, updating its total revenue request to $365 million.
In June 2026, the MPUC issued a verbal decision. Terms of the decision include:
•Estimated rate increase of approximately $211 million over two years (annual average increase of 2.9%).
•ROE of 9.60%, an increase from the current 9.25% ROE, while maintaining the equity ratio of 52.5%.
•Continuation of existing true-up mechanisms inclusive of the sales true-up, coupled with authorization of new tracker mechanisms.
A final written MPUC order is expected by July 31, 2026.
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 $62 million (8.2%) as updated in April 2026. 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.
In May 2026, NSP-Minnesota and certain intervenors reached a non-unanimous settlement, based on a total revenue increase of $38 million (4.9%) and a weighted average cost of capital of 7.21% (an increase from the previously authorized 7.16%).
An ALJ report is expected by September 2026 and a MPUC decision is expected in November 2026.
2022 Minnesota Electric Rate Case — In July 2023, the MPUC approved a three-year rate increase of approximately $332 million for 2022-2024, based on a ROE of 9.25% and an equity ratio of 52.5%.
NSP-Minnesota appealed certain aspects of the MPUC decision. In January 2025, the Minnesota Court of Appeals issued its opinion, which included reversing and remanding decisions related to executive compensation and prepaid pension asset back to the MPUC. In March 2026, the MPUC declined to modify the treatment of executive compensation. In July 2026, the MPUC declined to modify the treatment of prepaid pension asset.
2025 South Dakota Electric Rate Case — In June 2025, NSP-Minnesota filed a request with the 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%, an equity ratio of 52.87% and rate base of approximately $1.2 billion. Interim rates were implemented on Jan. 1, 2026.
In April 2026, NSP-Minnesota and SDPUC Staff filed a black box settlement agreement with the SDPUC, including a net annual electric rate increase of $26 million. In May 2026, the SDPUC approved the settlement agreement, and rates became effective July 1, 2026.
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. In March 2026, the NDPSC approved interim rates of $12 million effective April 1, 2026. The procedural schedule is yet to be determined.
NSP System
Pending and Recently Concluded Regulatory Proceedings
NSP-Minnesota and NSP-Wisconsin are actively engaged in multiple processes and proceedings to acquire resources to meet their identified generation resource needs.
•In October 2023, NSP-Minnesota issued an RFP seeking 1,200 MW of wind assets to replace capacity and reutilize interconnection rights associated with the retiring Sherco coal facilities. NSP-Minnesota filed for approval of recommended projects in March 2026. A decision is expected in the third quarter of 2026.
•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. Short-listed projects were announced in June 2026, and filing for requisite regulatory approval is expected by the end of 2026.
•NSP-Minnesota and NSP-Wisconsin may continue to file additional RFPs throughout 2026 and 2027 for resource needs as part of its Upper Midwest resource planning efforts.
Large Load Agreement — In the first quarter of 2026, NSP-Minnesota entered into an electric service agreement to power a new Google data center in Minnesota. Under the agreement, Google will pay all costs for its new service for the duration of the contract, in accordance with Minnesota’s regulatory and legislative requirements for large loads. If approved, the agreement is expected to result in approximately $1.1 billion of benefits to NSP-Minnesota’s customers. A request for approval of the electric service agreement, including a proposed Clean Energy Accelerator Charge for 1,900 MW of clean energy resources, was filed with the MPUC in April 2026. A decision is expected in early 2027.
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Approvals for 1,000 MW of resources for the Clean Energy Accelerator program are pending as part of existing resource acquisition processes. The remaining resources are expected to be requested in those processes by the end of 2026.
PSCo
Pending and Recently Concluded Regulatory Proceedings
2025 Colorado Electric Rate Case — In November 2025, PSCo filed an electric rate case with the 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.
In June 2026, PSCo, CPUC Staff and various other parties filed a comprehensive non-unanimous settlement agreement. The AARP, City of Boulder and the UCA oppose the settlement. Other parties either support portions of the settlement or do not oppose it. Terms of the settlement include:
•Revenue increase (excluding rider roll-ins) of $225 million (6.3% total, or an annual average of 2.05% since the last rate case), based on a 2025 historic test year using year-end rate base with limited forward looking known and measurable adjustments.
•ROE of 9.3% and equity ratio of 54.5%.
•A performance framework applicable to the operation of Comanche Unit 3 coal facility from effective date of rates through 2029.
•Transfer of the previous Transmission Cost Adjustment investments into rate base.
•Continuation of previously authorized trackers and deferrals.
A CPUC decision and implementation of final rates is anticipated in the third quarter of 2026.
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.
In July 2026, PSCo, CPUC Staff, the UCA, the Colorado Energy Office, Western Resource Advocates/Sierra Club, Energy Outreach Colorado and various other parties filed a comprehensive non-unanimous settlement agreement. Several parties either do not oppose or take no position on the settlement, and one transportation shipper opposes it. Key terms of the settlement include:
•Revenue increase of $123 million (7.5% total, or an annual average of 3.7% since the last rate case), based on a 2025 historic test year using average rate base with forward looking known and measurable adjustments.
•ROE of 9.2% and equity ratio of 54.5%.
Hearings to discuss the settlement took place in July 2026. A CPUC decision and implementation of final rates is anticipated in the fourth quarter of 2026.
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 3% compound annual sales growth through 2031 and a generation capacity need of approximately 5,400 MW.
PSCo filed a request for reconsideration of various aspects of the decision which were approved in February 2026. The RFP for the Phase II competitive solicitation process is 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 3,800 MW of approved acquisitions from the Near-Term Procurement RFP).
SPS
Pending and Recently Concluded Regulatory Proceedings
2025 New Mexico Electric Rate Case — In November 2025, SPS filed an electric rate case with the NMPRC. As updated in March 2026, SPS requested a revenue increase of $168 million (16.0%). The request was based on a future test year period ending Nov. 30, 2027, a ROE of 10.5%, an equity ratio of 56% and retail rate base of $3.9 billion.
In June 2026, SPS, New Mexico Department of Justice, New Mexico Large Customer Group and various other parties filed a comprehensive non-unanimous stipulation. NMPRC Staff opposes certain components of the stipulation.
Terms of the stipulation include:
•Base rate revenue increase of $90 million (7.7% total, or an annual average of 2.4% since the last rate case), based on the filed future test year.
•ROE of 9.5%.
•Equity ratio of 54.70%.
A hearing on the non-unanimous stipulation took place in July 2026. An NMPRC decision is anticipated in the fourth quarter of 2026, with implementation of rates expected in December 2026.
SPS Resource Acquisition — 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. SPS has received NMPRC approval of the CCN filings for the specific assets, and PUCT approval is expected in the third quarter. SPS is continuing to pursue approximately 2,800 MW of accredited resources, including approximately 4,000 MW of nameplate capacity company owned resources and approximately 500 MW of nameplate capacity PPAs.
In October 2025, SPS issued a RFP to solicit 870 MW of accredited capacity through 2032 (approximately 1,500 MW to 3,000 MW nameplate capacity, or more depending on resource mix), with additional resources to be evaluated to meet the New Mexico RPS compliance need. Bids were received in January 2026, and the portfolio selection report was publicly filed with the NMPRC in July 2026. Project CCNs are expected to be filed in late 2026 or early 2027.
The following resources are included in SPS’ preferred portfolio:
| Generation Resource Nameplate Capacity (in Megawatts) | Company Owned | PPAs | Total | ||||||||||||||
| Wind resources | 500 | 305 | 805 | ||||||||||||||
| Solar | 1,890 | — | 1,890 | ||||||||||||||
| Solar + storage | — | 1,000 | 1,000 | ||||||||||||||
| Natural gas | 233 | — | 233 | ||||||||||||||
| Total | 2,623 | 1,305 | 3,928 | ||||||||||||||
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Excess Liability Insurance Deferral – In early 2025, SPS filed requests with the NMPRC and PUCT for deferred accounting treatment for incremental excess liability insurance expense incurred as a result of the October 2024 policy renewal, estimated at approximately $30 million across the two jurisdictions. In October 2025, the NMPRC approved the request, resulting in a deferral of approximately $15 million of incremental excess liability insurance costs in 2025 and $7 million in the six months ended June 30, 2026. In January 2026, SPS, PUCT Staff and other intervenors filed a black box settlement expected to result in annual deferrals of approximately $8 million in 2026 and 2027. A PUCT decision is forthcoming.
Other
Tariffs, Trade Complaints and Federal Actions
Several trade cases related to anti-dumping and countervailing duty investigations are ongoing and we continue to monitor the potential impacts of these cases.
Executive orders have been issued imposing new global and country-specific tariffs on many imports, which may impact our procurement and development activities. Additionally, executive orders and actions from government agencies may impact the permitting of wind and solar facilities and the retirement of coal facilities.
Xcel Energy continues to assess the impacts of these tariffs, executive orders, trade complaints and federal policies on its business, including company owned projects and PPAs. Xcel Energy may seek regulatory relief, if required, in its jurisdictions.
Continued and/or further policy actions or other restrictions, disruptions in imports from key suppliers, or any new trade complaint could impact viability, timelines and costs of various projects and PPAs.
Large Load/Data Center Tariffs
In several of our jurisdictions, we have proposed tariffs applicable to large load customers. These tariffs are designed to allow us to serve these new customers and support local economic development while protecting existing customers from bearing the incremental costs to serve these loads.
While the details of these tariffs vary by jurisdiction, they generally include provisions to ensure data center customers pay the incremental costs to serve them, minimum demand or revenue requirements, termination or exit fees and customer security provisions. These tariffs and contracts are subject to approval by state regulatory commissions. The status of the filings in each jurisdiction is as follows.
NSP-Minnesota —The tariff, which was approved by the MPUC in June 2026, is mandatory for new loads over 100 MW and includes an incremental cost test, minimum initial term of 15 years, minimum bill provisions, termination and exit fees, and credit requirements.
NSP-Wisconsin — NSP-Wisconsin filed a proposed tariff in the second quarter of 2026, which would be mandatory for new loads over 100 MW and requires the customer pay for generation and other infrastructure costs needed to serve the load, if approved as filed. The proposed tariff also includes a minimum initial term of 15 years, minimum bill provisions, termination and exit fees, and credit requirements. A PSCW decision is expected in early 2027.
PSCo — The proposed tariff, filed in the second quarter of 2026, would be mandatory for new loads over 50 MW and requires the customer pay for generation and other infrastructure costs needed to serve the load. The proposed tariff also includes a minimum initial term of 15 years, minimum bill provisions, termination and exit fees, and credit requirements. A CPUC decision is expected in late 2026 or early 2027.
Similar large load tariff requests are expected to be filed in New Mexico and Texas by the end of 2026.
| Critical Accounting Policies and Estimates | ||
Preparation of the consolidated financial statements requires the application of accounting rules and guidance, as well as the use of estimates. Application of these policies involves judgments regarding future events, including the likelihood of success of particular projects, legal and regulatory challenges and anticipated recovery of costs. These judgments could materially impact the consolidated financial statements, based on varying assumptions. The financial and operating environment also may have a significant effect on the operation of the business and results reported. Items considered critical are included within the Xcel Energy Inc. Annual Report on Form 10-K for the year ended Dec. 31, 2025.
| Environmental Regulation | ||||||||||||||
Clean Air Act
Power Plant Greenhouse Gas Regulations — In April 2024, the EPA published final rules addressing control of CO2 emissions from the power sector. The rules regulate new natural gas generating units and emission guidelines for existing coal and certain natural gas generation.
Based on current estimates and assumptions, Xcel Energy has determined that due to scheduled plant retirements, there is minimal financial or operational impact associated with these requirements and believes that the cost of these initiatives or replacement generation would be recoverable through rates based on prior state commission practices.
In June 2025, the EPA proposed to repeal these and all other GHG emissions standards for the power sector. In the alternative, the EPA proposed to repeal a narrower subset of the 2024 regulations.
Endangerment Finding — In February 2026, the EPA issued a final rule repealing the 2009 Endangerment Finding and associated regulations addressing GHG emissions from new motor vehicles and engines under the Clean Air Act. Xcel Energy will monitor any additional proposed rules and evaluate the impacts of any final rule on the utility sector.
Emerging Contaminants of Concern
PFAS are man-made chemicals that are widely used in consumer products and can persist and bio-accumulate in the environment. Xcel Energy does not manufacture PFAS, but because PFAS are so ubiquitous in products and the environment, it may impact our operations.
In June 2024, the EPA finalized a rule that designated certain PFAS as hazardous substances under CERCLA. In July 2024, the EPA finalized another rule that set enforceable drinking water standards for certain PFAS.
Potential costs for these rules and any additional proposed regulations related to PFAS are uncertain and will be determined on a site specific basis where applicable. If costs are incurred, Xcel Energy believes the costs would be recoverable through rates based on prior state commission practices.
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Effluent Limitation Guidelines
In April 2024, the EPA published final rules under the Clean Water Act, setting Effluent Limitations Guidelines and Standards for steam generating coal plants. This rule establishes more stringent wastewater discharge standards for bottom ash transport water, flue-gas desulfurization wastewater and combustion residuals leachate from steam electric power plants, particularly coal-fired power plants. Based on current estimates and assumptions, Xcel Energy has determined that there is minimal financial or operational impact associated with these requirements and that any costs would be recoverable through rates based on prior state commission practices.
Derivatives, Risk Management and Market Risk | ||
We are exposed to a variety of market risks in the normal course of business. Market risk is the potential loss that may occur as a result of adverse changes in the market or fair value for a particular instrument or commodity. All financial and commodity-related instruments, including derivatives, are subject to market risk.
Xcel Energy is exposed to the impact of adverse changes in price for energy and energy-related products, which is partially mitigated by the use of commodity derivatives. In addition to ongoing monitoring and maintaining credit policies intended to minimize overall credit risk, management takes steps to mitigate changes in credit and concentration risks associated with its derivatives and other contracts, including parental guarantees and requests of collateral. While we expect that the counterparties will perform on the contracts underlying our derivatives, the contracts expose us to credit and non-performance risk.
Distress in the financial markets may impact counterparty risk and the fair value of the securities in the nuclear decommissioning fund and pension fund.
Commodity Price Risk — We are exposed to commodity price risk in our electric and natural gas operations. Commodity price risk is managed by entering into long and short-term physical purchase and sales contracts for electric capacity, energy and energy-related products and fuels used in generation and distribution activities.
Commodity price risk is also managed through the use of financial derivative instruments. Our risk management policy allows us to manage commodity price risk within each rate-regulated operation per commission approved hedge plans.
Wholesale and Commodity Trading Risk — Xcel Energy conducts various wholesale and commodity trading activities, including the purchase and sale of electric capacity, energy, energy-related instruments and natural gas-related instruments, including derivatives. Our risk management policy allows management to conduct these activities within guidelines and limitations as approved by our risk management committee.
Fair value of net commodity trading contracts as of June 30, 2026:
| Futures / Forwards Maturity | ||||||||||||||||||||||||||||||||
| (Millions of Dollars) | Less Than 1 Year | 1 to 3 Years | 4 to 5 Years | Greater Than 5 Years | Total Fair Value | |||||||||||||||||||||||||||
NSP-Minnesota (a) | $ | (8) | $ | (12) | $ | (2) | $ | (1) | $ | (23) | ||||||||||||||||||||||
NSP-Minnesota (b) | (3) | (10) | (1) | (2) | (16) | |||||||||||||||||||||||||||
PSCo (a) | (1) | — | — | — | (1) | |||||||||||||||||||||||||||
PSCo (b) | (1) | — | — | — | (1) | |||||||||||||||||||||||||||
| $ | (13) | $ | (22) | $ | (3) | $ | (3) | $ | (41) | |||||||||||||||||||||||
| Options Maturity | ||||||||||||||||||||||||||||||||
| (Millions of Dollars) | Less Than 1 Year | 1 to 3 Years | 4 to 5 Years | Greater Than 5 Years | Total Fair Value | |||||||||||||||||||||||||||
NSP-Minnesota (b) | $ | — | $ | 17 | $ | 6 | $ | — | $ | 23 | ||||||||||||||||||||||
| $ | — | $ | 17 | $ | 6 | $ | — | $ | 23 | |||||||||||||||||||||||
(a)Prices actively quoted or based on actively quoted prices.
(b)Prices based on models and other valuation methods.
Changes in the fair value of commodity trading contracts before the impacts of margin-sharing for the six months ended June 30:
| (Millions of Dollars) | 2026 | 2025 | ||||||||||||
| Fair value of commodity trading net contracts outstanding at Jan. 1 | $ | (15) | $ | (2) | ||||||||||
| Contracts realized or settled during the period | 3 | 1 | ||||||||||||
| Commodity trading contract additions and changes during the period | (6) | (7) | ||||||||||||
| Fair value of commodity trading net contracts outstanding at June 30 | $ | (18) | $ | (8) | ||||||||||
A 10% increase and 10% decrease in forward market prices for Xcel Energy’s commodity trading contracts would have likewise increased and decreased pretax income from continuing operations by approximately $2 million and $3 million at June 30, 2026 and June 30, 2025.
The utility subsidiaries’ commodity trading operations measure the outstanding risk exposure to price changes on contracts and obligations using an industry standard methodology known as VaR. VaR expresses the potential change in fair value of the outstanding contracts and obligations over a particular period of time under normal market conditions.
The VaRs for the NSP-Minnesota and PSCo commodity trading operations, excluding both non-derivative transactions and derivative transactions designated as normal purchases and normal sales, calculated on a consolidated basis using a Monte Carlo simulation with a 95% confidence level and a one-day holding period, were as follows:
| (Millions of Dollars) | Three Months Ended June 30 | Average | High | Low | ||||||||||||||||||||||
| 2026 | $ | — | $ | 1 | $ | 1 | $ | — | ||||||||||||||||||
| 2025 | 1 | 1 | 1 | — | ||||||||||||||||||||||
Interest Rate Risk — Xcel Energy is subject to interest rate risk. Our risk management policy allows interest rate risk to be managed through the use of fixed rate debt, floating rate debt and interest rate derivatives.
A 100-basis point change in the benchmark rate on Xcel Energy’s variable rate debt would impact pretax interest expense annually by approximately $25 million and $8 million at June 30, 2026 and 2025, respectively
NSP-Minnesota maintains a nuclear decommissioning fund, as required by the NRC. The nuclear decommissioning fund is subject to interest rate and equity price risk. The fund is invested in a diversified portfolio of debt securities, equity securities and other investments. These investments may be used only for the purpose of decommissioning NSP-Minnesota’s nuclear generating plants.
Fluctuations in equity prices or interest rates affecting the nuclear decommissioning fund do not have a direct impact on earnings due to the application of regulatory accounting. Realized and unrealized gains on the decommissioning fund investments are deferred as an offset of NSP-Minnesota’s regulatory liability for nuclear decommissioning costs.
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The value of pension and postretirement plan assets and benefit costs are impacted by changes in discount rates and expected return on plan assets. Xcel Energy’s ongoing pension and postretirement investment strategy is based on plan-specific investment recommendations that seek to optimize potential investment risk and minimize interest rate risk associated with changes in the obligations as a plan’s funded status increases over time. The impacts of fluctuations in interest rates on pension and postretirement costs are mitigated by pension cost calculation methodologies and regulatory mechanisms that minimize the earnings impacts of such changes.
Credit Risk — Xcel Energy is also exposed to credit risk. Credit risk relates to the risk of loss resulting from counterparties’ nonperformance on their contractual obligations. Xcel Energy maintains credit policies intended to minimize overall credit risk and actively monitors these policies to reflect changes and scope of operations.
Credit exposure is monitored, and when necessary, the activity with a specific counterparty is limited until credit enhancement is provided. Distress in the financial markets could increase our credit risk.
Xcel Energy’s subsidiaries are subject to credit risk from contracts with generating equipment manufacturers and other suppliers that require deposits or milestone payments. In the event of non-performance by these counterparties, the Xcel Energy subsidiaries could experience credit losses, increased costs or project delays. Xcel Energy frequently seeks to mitigate this risk by requiring parent guarantees, letters of credit or other types of credit support.
Xcel Energy is also subject to credit risk for all wholesale, trading and non-trading commodity counterparties and employs credit risk controls, such as letters of credit, parental guarantees, master netting agreements and termination provisions.
At June 30, 2026, a 10% increase in commodity prices would have resulted in an increase in credit exposure of $30 million, while a decrease in prices of 10% would have resulted in a decrease in credit exposure of $27 million. At June 30, 2025, a 10% increase in commodity prices would have resulted in an increase in credit exposure of $39 million, while a decrease in prices of 10% would have resulted in a decrease in credit exposure of $38 million.
Fair Value Measurements | ||
Derivative contracts, with the exception of those designated as normal purchases and normal sales, are reported at fair value. Xcel Energy’s investments held in the nuclear decommissioning fund, rabbi trusts, pension and other postretirement funds are also subject to fair value accounting. See Note 8 to the consolidated financial statements for further information.
Liquidity and Capital Resources | ||
Cash Flows
Operating Cash Flows
| (Millions of Dollars) | Six Months Ended June 30 | |||||||
| Cash provided by operating activities — 2025 | $ | 2,109 | ||||||
| Components of change — 2026 vs. 2025 | ||||||||
| Higher net income | 215 | |||||||
| Non-cash transactions | (219) | |||||||
| Changes in deferred income taxes | (310) | |||||||
| Changes in working capital | 769 | |||||||
| Changes in net regulatory and other assets and liabilities | 233 | |||||||
| Cash provided by operating activities — 2026 | $ | 2,797 | ||||||
Net cash provided by operating activities increased $688 million for the six months ended June 30, 2026 compared with the prior year. The increase was largely due to insurance reimbursements for the Marshall Wildfire and Smokehouse Creek Fire Complex settlement activity.
Investing Cash Flows
| (Millions of Dollars) | Six Months Ended June 30 | |||||||
| Cash used in investing activities — 2025 | $ | (4,430) | ||||||
| Components of change — 2026 vs. 2025 | ||||||||
| Increased capital expenditures | (1,555) | |||||||
| Other investing activities | 26 | |||||||
| Cash used in investing activities — 2026 | $ | (5,959) | ||||||
Net cash used in investing activities increased $1,529 million for the six months ended June 30, 2026 compared with the prior year. The increase in capital expenditures was largely due to continued system investment in renewable and transmission projects.
Financing Cash Flows
| (Millions of Dollars) | Six Months Ended June 30 | |||||||
| Cash provided by financing activities — 2025 | $ | 3,596 | ||||||
| Components of change — 2026 vs. 2025 | ||||||||
| Higher net short-term debt proceeds | 835 | |||||||
| Higher long-term debt issuances, net of repayments | 1,667 | |||||||
| Lower proceeds from issuance of common stock | (1,132) | |||||||
| Other financing activities | (68) | |||||||
| Cash provided by financing activities — 2026 | $ | 4,898 | ||||||
Net cash provided by financing activities increased $1,302 million for the six months ended June 30, 2026 compared with the prior year. The increase was largely related to additional debt to fund capital investment, partially offset by decreased issuances of common stock.
Capital Requirements
Xcel Energy expects to meet future financing requirements by periodically issuing short-term debt, long-term debt, common stock, hybrid and other securities to maintain desired capitalization ratios.
32
Pension Fund — Xcel Energy’s pension assets are invested in a diversified portfolio of domestic and international equity securities, short-term to long-duration fixed income securities, and alternative investments, including private equity, real estate and hedge funds.
•In January 2026, contributions of $75 million were made to Xcel Energy’s pension plans.
•In 2025, contributions of $125 million were made to Xcel Energy’s pension plans.
•For future years, contributions will be made as deemed appropriate based on evaluation of various factors including the funded status of the plans, minimum funding requirements, interest rates and expected investment returns.
Capital Sources
Short-Term Funding Sources — Xcel Energy uses a number of sources to fulfill short-term funding needs, including operating cash flow, notes payable, commercial paper and bank lines of credit. The amount and timing of short-term funding needs depend on financing needs for construction expenditures, working capital and dividend payments.
Short-Term Investments — Xcel Energy Inc., NSP-Minnesota, NSP-Wisconsin, PSCo and SPS maintain cash operating and short-term investment accounts.
Credit Facilities — As of July 28, 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 | $ | 1,055 | $ | 945 | $ | 8 | $ | 953 | ||||||||||||||||||||||
| PSCo | 1,200 | 48 | 1,152 | 18 | 1,170 | |||||||||||||||||||||||||||
| NSP-Minnesota | 800 | 44 | 756 | 113 | 869 | |||||||||||||||||||||||||||
| SPS | 600 | — | 600 | 817 | 1,417 | |||||||||||||||||||||||||||
| NSP-Wisconsin | 150 | — | 150 | 135 | 285 | |||||||||||||||||||||||||||
| Total | $ | 4,750 | $ | 1,147 | $ | 3,603 | $ | 1,091 | $ | 4,694 | ||||||||||||||||||||||
(a)Credit facilities expire in December 2029.
(b)Includes outstanding commercial paper and letters of credit.
Term Loan Agreement — In January 2026, Xcel Energy Inc. entered into a $1.5 billion, 364-Day Delayed Draw Term Loan Agreement and as of July 28, 2026 had borrowed $1.5 billion under the term loan facility.
Short-Term Debt — Xcel Energy Inc., NSP-Minnesota, NSP-Wisconsin, PSCo and SPS each have individual commercial paper programs. As of June 30, 2026, the authorized levels for these commercial paper programs are:
•$2 billion for Xcel Energy Inc.
•$1.2 billion for PSCo.
•$800 million for NSP-Minnesota.
•$600 million for SPS.
•$150 million for NSP-Wisconsin.
Money Pool — Xcel Energy received FERC approval to establish a utility money pool arrangement with the utility subsidiaries, subject to receipt of required state regulatory approvals. The utility money pool allows for short-term investments in and borrowings between the utility subsidiaries.
Xcel Energy may make investments in the utility subsidiaries at market-based interest rates; however, the money pool arrangement does not allow the utility subsidiaries to make investments in Xcel Energy. The money pool balances are eliminated in consolidation. NSP-Minnesota, NSP-Wisconsin, PSCo and SPS participate in the money pool pursuant to approval from their respective state regulatory commissions.
2026 Financing Activity — Xcel Energy and its utility subsidiaries issued or plan to issue the following long-term debt:
| Issuer | Security | Amount | Status | Tenor | Coupon | |||||||||||||||||||||||||||
| Xcel Energy Inc. | Junior subordinated notes | $ | 800 | million | Completed | 30 year | 5.75% fixed-to-fixed reset rate | |||||||||||||||||||||||||
| PSCo | First mortgage bonds | 1,300 | million | Completed | 3 year & 10 year | 4.15% & 5.05% | ||||||||||||||||||||||||||
| NSP-Minnesota | First mortgage bonds | 1,200 | million | Completed | 10 year & 30 year | 4.85% & 5.55% | ||||||||||||||||||||||||||
| NSP-Wisconsin | First mortgage bonds | 250 | million | Completed | 15 year | 5.48% | ||||||||||||||||||||||||||
| SPS | First mortgage bonds | 1,200 | million | Completed | 10 year & 30 year | 5.30% & 5.875% | ||||||||||||||||||||||||||
| PSCo | First mortgage bonds | 1,100 | million | Upcoming | N/A | N/A | ||||||||||||||||||||||||||
| Xcel Energy Inc. | Senior unsecured notes | 700 | million | Upcoming | N/A | N/A | ||||||||||||||||||||||||||
During the six months ended June 30, 2026, Xcel Energy Inc. entered forward sale agreements for shares of common stock totaling 42.5 million shares (minimum expected proceeds of $3.2 billion). There were no shares issued in at-the-market cash transactions or settlements of forward sale agreements during the period. As of June 30, 2026, 69.7 million shares remain unsettled on forward equity agreements and collared forward equity agreements (minimum expected proceeds of $5.2 billion).
Long-Term Borrowings, Equity Issuances and Other Financing Instruments — Xcel Energy may issue equity through its ATM 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.
See Note 4 to the consolidated financial statements for further information.
Off-Balance-Sheet Arrangements
Xcel Energy does not have any off-balance-sheet arrangements, other than those currently disclosed, that have or are reasonably likely to have a current or future effect on financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that is material to investors.
33
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 remainder of 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 $480 million to $490 million.
•O&M expenses are projected to increase ~3%.
•Depreciation expense is projected to increase approximately $140 million to $150 million. The decrease from prior guidance is primarily due to nuclear life extensions, which is offset by lower revenue.
•Property taxes are projected to increase $30 million to $40 million.
•Interest expense (net of AFUDC - debt) is projected to increase $240 million to $250 million, net of interest income.
•AFUDC - equity is projected to increase $150 million to $160 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.
ITEM 3 — QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK | ||
There have been no material changes to the market risk disclosure included in our Annual Report on Form 10-K for the year ended Dec. 31, 2025 under “Derivatives, Risk Management and Market Risk.”
ITEM 4 — CONTROLS AND PROCEDURES | ||
Disclosure Controls and Procedures
Xcel Energy maintains a set of disclosure controls and procedures designed to ensure that information required to be disclosed in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in SEC rules and forms. In addition, the disclosure controls and procedures ensure that information required to be disclosed is accumulated and communicated to management, including the CEO and CFO, allowing timely decisions regarding required disclosure.
As of June 30, 2026, based on an evaluation carried out under the supervision and with the participation of Xcel Energy’s management, including the CEO and CFO, of the effectiveness of its disclosure controls and procedures, the CEO and CFO have concluded that Xcel Energy’s disclosure controls and procedures were effective.
Internal Control Over Financial Reporting
No changes in Xcel Energy’s internal control over financial reporting occurred during the most recent fiscal quarter that materially affected, or are reasonably likely to materially affect, Xcel Energy’s internal control over financial reporting.
PART II — OTHER INFORMATION
ITEM 1 — LEGAL PROCEEDINGS | ||
Xcel Energy is involved in various litigation matters in the ordinary course of business. The assessment of whether a loss is probable or is a reasonable possibility, and whether the loss or a range of loss is estimable, often involves a series of complex judgments about future events. Management maintains accruals for losses probable of being incurred and subject to reasonable estimation.
Management is sometimes unable to estimate an amount or range of a reasonably possible loss in certain situations, including but not limited to when (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution of such matters, including a possible eventual loss.
For current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, would have a material effect on Xcel Energy’s consolidated financial statements. Legal fees are generally expensed as incurred.
See Note 10 to the consolidated financial statements and Part I Item 2 for further information.
ITEM 1A — RISK FACTORS | ||
Xcel Energy’s risk factors are documented in Item 1A of Part I of its Annual Report on Form 10-K for the year ended Dec. 31, 2025, which is incorporated herein by reference. There have been no material changes from the risk factors previously disclosed in the Form 10-K.
ITEM 2 — UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS | ||
Purchases of Equity Securities by the Issuer and Affiliated Purchaser:
For the quarter ended June 30, 2026, no equity securities that are registered by Xcel Energy Inc. pursuant to Section 12 of the Securities Exchange Act of 1934 were purchased by or on behalf of us or any of our affiliated purchasers.
ITEM 5 — OTHER INFORMATION | ||
None of the Company’s directors or officers adopted terminated
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ITEM 6 — EXHIBITS | ||
| * | Indicates incorporation by reference | ||||
| Exhibit Number | Description | Report or Registration Statement | Exhibit Reference | ||||||||
| Xcel Energy Inc. Form 8-K dated May 16, 2012 | 3.01 | ||||||||||
| Xcel Energy Inc Form 8-K dated August 23, 2023 | 3.02 | ||||||||||
| SPS Form 8-K dated June 29, 2026 | 4.02 | ||||||||||
| NSP-Wisconsin Form 8-K dated June 10, 2026 | 4.01 | ||||||||||
| Xcel Energy Inc. Form 8-K dated July 29, 2026 | 10.01 | ||||||||||
| 101.INS | Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document | ||||||||||
| 101.SCH | Inline XBRL Schema | ||||||||||
| 101.CAL | Inline XBRL Calculation | ||||||||||
| 101.DEF | Inline XBRL Definition | ||||||||||
| 101.LAB | Inline XBRL Label | ||||||||||
| 101.PRE | Inline XBRL Presentation | ||||||||||
| 104 | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101) | ||||||||||
35
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 thereunto duly authorized.
| XCEL ENERGY INC. | ||||||||
| July 30, 2026 | By: | /s/ MELISSA L. OSTROM | ||||||
| Melissa L. Ostrom | ||||||||
| Senior Vice President, Controller | ||||||||
| (Principal Accounting Officer) | ||||||||
| By: | /s/ BRIAN J. VAN ABEL | |||||||
| Brian J. Van Abel | ||||||||
| Executive Vice President, Chief Financial Officer | ||||||||
| (Principal Financial Officer) | ||||||||
36
Exhibit 10.02
XCEL ENERGY INC.
NONQUALIFIED DEFERRED COMPENSATION PLAN
(2026 Restatement)
First Effective January 1, 2000, restated effective January 1, 2002, January 1, 2009, and August 1, 2026
XCEL ENERGY INC. NONQUALIFIED DEFERRED COMPENSATION PLAN
(2026 Restatement)
TABLE OF CONTENTS
SECTION 1 INTRODUCTION................................................................................................................1
SECTION 2 PARTICIPATION...............................................................................................................5
SECTION 3 CREDITS AND ADJUSTMENTS OF ACCOUNTS.......................................................6
SECTION 4 VESTING OF ACCOUNT..................................................................................................9
SECTION 5 PAYMENT..........................................................................................................................10
SECTION 6 UNFUNDED PLAN............................................................................................................14
SECTION 7 AMENDMENT AND TERMINATION.. ........................................................................15
SECTION 8 DETERMINATIONS – RULES AND REGULATIONS...............................................16
SECTION 9 PLAN ADMINISTRATION..............................................................................................17
SECTION 10 DISCLAIMERS................................................................................................................19
ADDENDUM A DESIGNATED EMPLOYERS AND DESIGNATED AFFILIATES.....................20
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XCEL ENERGY INC. NONQUALIFIED DEFERRED COMPENSATION PLAN
(2026 Restatement)
SECTION 1
INTRODUCTION
INTRODUCTION
1.1Purpose. Effective January 18, 1980, Northern States Power Company (NSP) established the NSP Deferred Compensation Plan, which was subsequently restated as amended through January 1, 1992 (the “NSP 1992 Plan”).
Effective July 1, 1998, New Century Energies, Inc. (NCE) established the Salary Deferral and Supplemental Savings Plan for Executive Officers, and the Salary Deferral and Supplemental Savings Plan for Key Managers (the NCE Nonqualified Plans).
Effective January 1, 2000, NSP established the NSP Nonqualified Deferred Compensation Plan (2000 Statement), a separate plan from the NSP Deferred Compensation Plan. (The NSP Deferred Compensation Plan, the NSP 1992 Plan, and the NCE Nonqualified Plans are collectively referred to as the “Former Nonqualified Plans.”) As of August 2000, NSP and NCE merged to become Xcel Energy Inc.
Effective January 1, 2002, the NSP Nonqualified Deferred Compensation Plan (2000 Statement) and the Former Nonqualified Plans were combined into a single plan renamed the “Xcel Energy Inc. Nonqualified Deferred Compensation Plan,” with respect to amounts credited to Accounts on and after that date.
Effective January 1, 2009, the Plan was amended and restated to incorporate all amendments since January 1, 2002, and to comply with Section 409A of the Internal Revenue Code of 1986, as amended, and related guidance. From January 1, 2005, through the effective date of that restatement, the Plan was operated in good faith compliance with applicable Section 409A guidance, including IRS Notice 2005-1, and participants were permitted to make transitional payment elections as described in Section 5.
Effective August 1, 2026, this Plan was further amended and restated to incorporate all amendments since January 1, 2009, reflect the Plan’s current governance structure, and revise certain eligibility provisions. This Plan is a nonqualified, unfunded elective deferral plan that allows eligible management and highly compensated employees to defer certain compensation that would otherwise be paid to them.
1.2Definitions. When the following terms are used herein with initial capital letters, they shall have the following meanings:
1.2.1Account – the bookkeeping account(s) maintained to reflect a Participant’s or Beneficiary’s interest in the Plan, representing an unfunded and unsecured general obligation of the Employer. The Principal Sponsor may establish one or more Accounts or subaccounts, including Pre-Tax Deferral, Transfer, Employer Matching Credit, Employer Discretionary Credit, and, effective May 21, 2013, Long-Term Incentive
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Deferral subaccounts (which are frozen to new deferrals on and after January 1, 2026), as well as such other accounts or subaccounts as deemed necessary. Except as the context otherwise requires, “Account” refers to a Participant’s or Beneficiary’s total interest under the Plan.
1.2.2Administrator – means the Principal Sponsor, or if designated by the Principal Sponsor, the Committee or such other person or persons designated by the Committee as provided in Section 9.
1.2.3Affiliate – a business entity that is at least 50% owned or affiliated in ownership with the Principal Sponsor, as defined in regulations issued under Section 409A of the Code.
1.2.4Annual Incentive – the annual incentive award, if any, payable to a Participant from time to time pursuant to the Employer’s annual incentive plan or plans. For purposes of this Section, all or part of an Annual Incentive may be considered “performance-based compensation” if the award is based on services performed over a period of at least twelve months and meets the definition of performance-based compensation found in Code Section 409A and the regulations issued thereunder.
1.2.5Base Salary – a Participant’s regular annual base salary in effect from time to time during each Plan Year, unreduced for any salary deferrals under any Employer savings, incentive or other employee benefit plan, whether or not the same is qualified under Section 401A of the Code.
1.2.6Beneficiary – a person designated on a Beneficiary Designation Form in writing by a Participant (or automatically by operation of this Plan Statement) to receive all or a part of the Participant's Account in the event of the Participant's death prior to full distribution thereof. A person so designated shall not be considered a Beneficiary until the death of the Participant.
1.2.7Beneficiary Designation – the process prescribed by the Principal Sponsor upon which a Participant may designate a Beneficiary.
1.2.8Code – the Internal Revenue Code of 1986, as amended from time to time.
1.2.9Committee – a Committee appointed pursuant to Section 9.
1.2.10Distribution Election – the process prescribed by the Principal Sponsor pursuant to which a Participant may elect a form of distribution of the Participant’s Account under the Plan as provided by Section 5.3.
1.2.11Disability – the Participant is, by reason of any medically determinable mental or physical impairment that can be expected to result in death or can be expected to last for a continuous period of not less than twelve months, receiving income replacement benefits for a period of not less than six months under the Employer’s long-term disability plan.
1.2.12Effective Date – January 1, 2002. The Effective Date of this Restatement is August 1, 2026, except as otherwise provided herein.
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1.2.13Employer – the Principal Sponsor and any business entity that is designated by the Principal Sponsor and identified on Addendum A as employing employees that are eligible to be selected to participate in this Plan.
1.2.14Employer Matching Credit Subaccount – the Account, if any, maintained for a Participant to which is credited Employer matching credits pursuant to Section 3.3(c).
1.2.15Financial Hardship – a severe financial hardship resulting from (i) an illness or accident of the Participant, the Participant’s spouse, Beneficiary, or dependent (as defined in Code §152, determined without regard to §§152(b)(1), (b)(2), and (d)(1)(B)); (ii) loss of the Participant’s property due to casualty; or (iii) other similar extraordinary and unforeseeable circumstances arising as a result of events beyond the Participant’s control. A distribution shall not be made to the extent the hardship is or may be relieved through insurance or other reimbursement, liquidation of assets (to the extent such liquidation would not itself cause severe financial hardship), or cessation of deferrals under the Plan. Any distribution shall be limited to the amount reasonably necessary to satisfy the emergency need, including amounts necessary to pay reasonably anticipated income taxes or penalties resulting from the distribution.
1.2.16Investment Election – the process prescribed by the Principal Sponsor from time to time pursuant to which a Participant may select the hypothetical investment of the Participant’s Account pursuant to the provisions of Section 3.
1.2.17Investment Fund – any of the hypothetical investment funds established by the Principal Sponsor pursuant to the provisions of Section 3.
1.2.18Long-Term Incentive Subaccount – the account, if any, maintained for a Participant to which are credited deferrals of Long-Term Incentive Awards payable to the Participant through January 1, 2026. For purposes of this Section, a Long-Term Incentive Award may be considered “performance-based compensation” if the award is based on services performed over a period of at least twelve months and meets the definition of “performance-based compensation” found in Code Section 409A and the regulations issued thereunder.
1.2.19Participant – an employee (other than an employee whose employment terms are subject to a collective bargaining agreement) of an Employer who is a member of a select group of management or highly compensated employees and who elects to participate in this Plan. Effective on and after August 1, 2026, eligibility has changed to be limited to management level employees who have been classified as SLG, BVP or Executive Committee.
1.2.20Plan – the nonqualified, income deferral program maintained by the Principal Sponsor established for the benefit of Participants eligible to participate therein, as set forth in this Plan Statement. (As used herein, "Plan" does not refer to the documents pursuant to which the Plan is maintained. Those documents are referred to herein as the "Plan Statement"). The Plan shall be referred to as the “Xcel Energy Inc. Nonqualified Deferred Compensation Plan.”
1.2.21Plan Statement – this document entitled "XCEL ENERGY INC. NONQUALIFIED DEFERRED COMPENSATION PLAN (2026 Restatement)" as adopted by the Principal
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Sponsor effective as of August 1, 2026, as the same may be amended from time to time thereafter.
1.2.22Plan Year – the twelve (12) consecutive month period ending December 31st.
1.2.23Pre-Tax Deferrals – the Base Salary and Annual Incentive deferrals made to the Plan pursuant to the provisions of Section 3.
1.2.24Pre-Tax Deferral Subaccount – the Account maintained for each Participant to which is credited such Participant’s Pre-Tax Deferrals pursuant to Section 3, below.
1.2.25Principal Sponsor – Xcel Energy Inc., a Minnesota corporation.
1.2.26Separation from Service – means a Participant’s death, retirement, or other termination of employment with the Employer or any Affiliate, determined in accordance with Section 409A of the Code and applicable Treasury Regulations and guidance.
A Participant who remains employed but is not actively providing services (including during a garden leave or similar arrangement) will not be considered to have incurred a Separation from Service solely because the Participant is no longer actively providing services.
For clarity, a Participant’s receipt of long-term disability benefits, or status as being on long-term disability leave, does not by itself constitute a Separation from Service or otherwise cause payment of the Participant’s Account under the Plan. A Separation from Service occurs only when the Participant’s employment with the Employer or any Affiliate has actually terminated or is otherwise determined to have terminated under Code Section 409A and applicable Treasury Regulations.
In the case of a Participant who provides services as an independent contractor, Separation from Service means a good-faith and complete termination of the contractual relationship under which services are performed for the Employer or any Affiliate.
1.2.27Transfer Subaccount – the Account, if any, maintained for a Participant to which is credited some part or all of the benefits of the Participant under any other nonqualified plan maintained by the Employer or any Former Nonqualified Plan. Such amounts may be transferred to this Plan only upon the approval of the Principal Sponsor, subject to such rules and conditions as the Principal Sponsor may impose, and only if the Principal Sponsor determines that such transfer can occur in a manner that does not violate the requirements of Code §409A.
1.2.28Trust – the Trust agreement, if any, for the Plan, which shall be a grantor trust, established by the Principal Sponsor.
1.2.29Trust Fund – the fund or funds, if any, established by the Principal Sponsor pursuant to Section 6.
1.2.30Trustee – that person or entity, if any, which shall have been appointed by the Principal Sponsor to hold the assets of any Trust created pursuant to Section 6.
1.2.31Valuation Date – the last day of each calendar quarter of the Plan Year, and such other time or times as determined by the Principal Sponsor.
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SECTION 2
PARTICIPATION
PARTICIPATION
2.1Eligibility. A Participant may elect to make contributions to the Plan as follows:
2.1.1 Ongoing Participation. An eligible Participant may elect to defer Base Salary and/or Annual Incentive by submitting a deferral election in the manner and by the deadline established by the Principal Sponsor. For Base Salary and Annual Incentive, elections must be made no later than December 31 of the Plan Year preceding the Plan Year to which the election applies. For Participants who made a deferral election to defer Base Salary and/or Annual Incentive for Plan Year 2026, and who would not otherwise be eligible in future years due to the eligibility requirements in the definition of “Participant”, shall be permitted to continue participation in the Plan effective with Plan Year 2027 and beyond so long as they maintain continuous deferral elections under the Plan. If such a Participant ceases deferrals for any Plan Year effective 2027 and beyond, the Participant shall not be eligible to recommence participation in the Plan unless the Participant satisfies the eligibility requirements in the definition of “Participant”.
2.2Cessation of Eligibility. If a Participant has a Separation from Service, the Participant’s deferrals shall cease as of the date of Separation from Service. If a Participant no longer satisfies the eligibility criteria during a Plan Year, deferrals continue through the end of the Plan Year and then stop for future years. The individual remains a Participant until their Account (if any) is distributed from the Plan.
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SECTION 3
CREDITS AND ADJUSTMENTS OF ACCOUNTS
CREDITS AND ADJUSTMENTS OF ACCOUNTS
3.1Credits.
3.1.1Employee Deferrals.
(a)Basic Base Salary Deferrals. For each Plan Year, a Participant may elect to make a pre-tax Base Salary deferral of up to 75% of such Participant’s Base Salary, subject to any necessary withholding for payroll, FICA, and other employment taxes. The Employer shall withhold the Participant’s share of such taxes from the portion of the Participant’s Base Salary that is not being deferred, in a manner determined by the Principal Sponsor. If necessary, the Principal Sponsor may reduce the Participant’s Base Salary deferral in order to satisfy any required withholding obligations.
(b)Annual Incentive Deferrals. For each Plan Year, a Participant may elect to make a pre-tax deferral of up to 100% of such Participant’s Annual Incentive, subject to any necessary withholding for payroll, FICA, and other employment taxes. The Employer shall withhold the Participant’s share of such taxes from the portion of the Participant’s Annual Incentive that is not being deferred, in a manner determined by the Principal Sponsor. If necessary, the Principal Sponsor may reduce the Participant’s Annual Incentive deferral in order to satisfy any required withholding obligations.
3.2Rules Regarding Participant Contributions. Each deferral election made by a Participant shall be subject to the following rules and conditions:
3.2.1Timing. A Participant’s deferral election shall be made and shall become effective as provided in Section 2.1.1. If a Participant fails to submit a deferral election when the Participant is eligible to do so, such Participant shall be deemed to have elected not to contribute for the Plan Year to which such failure relates.
3.2.2Irrevocable. Each Participant’s deferral election for a Plan Year shall be irrevocable and shall remain in effect for all such Base Salary and Annual Incentive paid during the Plan Year to which the Participant’s deferral election relates. Notwithstanding the foregoing, a Participant’s deferral election and corresponding contributions to the Plan shall cease upon the occurrence of any of the following events:
(a)The Participant incurs a Financial Hardship, or receives a Financial Hardship distribution from this Plan or from the Xcel Energy 401(k) Savings Plan, in which case such Participant’s Pre-Tax Deferrals for the Plan Year in which such distribution is made shall be cancelled for the Plan Year of such Financial Hardship or Financial Hardship distribution and for the next following Plan Year;
(b)The Participant’s Separation from Service;
(c)The Participant’s death.
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3.2.3Crediting of Deferred Compensation. A Participant’s Pre-Tax Deferrals and any corresponding Employer Matching Credit, if any, shall be credited to the Participant’s Account as of the payroll date such compensation is withheld from the Participant’s paycheck, or as soon as reasonably practicable thereafter.
3.3Employer Credits.
(a)Base Salary Deferrals. Within a reasonable time following the date that the amount elected by the Participant as a Base Salary deferral would otherwise be paid to such Participant, the Employer shall credit the Participant’s Pre-Tax Deferral Subaccount with the amount of such contribution(s).
(b)Annual Incentive Deferrals. Within a reasonable time following the date that the amount elected by the Participant as an Annual Incentive would otherwise be paid to such Participant, the Employer shall credit the Participant’s Pre-Tax Deferral Subaccount with the amount of such contributions.
(c)Employer Matching Credits. Following each payroll cycle, the Employer Matching Credit Subaccount of each such Participant (other than a Participant subject to the Traditional Benefit under the Xcel Energy Pension Plan) who makes Pre-Tax Deferrals for a Plan Year, and whose Base Salary exceeds the limit of Code Section 401(a)(17), or whose maximum allowable elective deferral is limited by Code Sections 415 or 402(g) that otherwise prohibits the Participant from receiving a full match within the Xcel Energy 401(k) Savings Plan for the Plan Year shall be allocated an Employer Matching Credit. The Employer Matching Credit formula will be based on the Matching Contribution formula applicable to such Participant under the Xcel Energy 401(k) Savings Plan for the Plan Year, calculated as though none of the aforementioned limits apply.
(d)Transfer Credits. Any benefits transferred to this Plan (whether by merger, transfer, substitution or otherwise) on behalf of a Participant from another nonqualified Plan of the Employer (including any Former Nonqualified Plan) shall be credited to this Plan at their fair market value at the time of the transfer. Such amounts shall be credited to the Transfer Subaccount of the Participant, unless the Principal Sponsor, in its discretion, determines that such amounts shall be credited to another account of the Participant. Notwithstanding the foregoing, no transfer shall be made to this Plan unless such transfer and the form and payment of any transferred funds, can be made in a manner that does not violate the provisions of Code §409A.
3.4Adjustments of Account. Subject to such rules as may be prescribed by the Principal Sponsor from time to time, amounts shall be credited or debited to a Participant’s Account in connection with the deemed investment thereof as follows:
3.4.1Initial Election of Investment Funds. In connection with a Participant’s initial enrollment into the Plan, a Participant shall elect one or more Investment Funds on an Investment Election Form filed in the manner prescribed by the Principal Sponsor to be used as an index to determine the additional amounts to be credited or debited to such Participant’s Account. If a Participant fails to select any Investment Fund or if a Participant’s election of an Investment Fund shall, for any reason, be ineffective, such
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Participant shall be deemed to have elected the Federal Money Market Fund or such short-term index Investment Fund as may be determined from time to time in the discretion of the Principal Sponsor.
3.4.2Changes to Investment Fund Elections. A Participant may (but is not required to) elect in the manner prescribed by the Principal Sponsor, to add, delete or modify one or more of their Investment Fund(s) elections.
(a)Proportionate Allocation. Subject to such rules as the Principal Sponsor may from time to time prescribe, Participant investment elections described in this Section shall be made in increments of one percentage point (1%) of the Participant’s Account.
(b)Investment Funds. The Participant may elect one or more of the Investment Funds selected by the Principal Sponsor from time to time as hypothetical investments. The Principal Sponsor may, in its sole discretion, discontinue, substitute or add an Investment Fund. The Principal Sponsor shall also have the power to direct that any separate Investment Funds shall be consolidated with (or “mapped” to) any other Investment Fund having the same (or nearly the same) investment objectives. Each such change shall take effect at such time or times and under such rules as shall be established by the Principal Sponsor.
3.4.3Debits and Credits to Accounts. Plan investments and earnings adjustments shall be made in accordance with the following rules:
(a)To the extent administratively feasible, any Account will be valued daily at the fair market value thereof by adding (A) the fair market value of all investments held in the Account, (B) any accrued interest or declared dividends on such investments not reflected in (A) above, and (C) an amount equal to the cash then held in the Account; and subtracting therefrom any liabilities of the Account. Participants’ Accounts will be adjusted daily by allocating among them the earnings or losses of each Investment Fund since the previous day in proportion to each Participant’s portion of the Investment Fund balance immediately following the previous day’s adjustment. To the extent daily Account valuations and adjustments are not administratively feasible, such valuations and adjustments shall occur as frequently as administratively feasible.
(b)Withdrawals and distributions shall be made in cash and made pursuant to Section 5. The amount paid upon such a withdrawal or distribution shall be based on the value immediately after the adjustment of a Participant’s Account on the effective date of the withdrawal or distribution.
Notwithstanding the foregoing, the Principal Sponsor may establish revised or additional rules for the adjustment of Accounts including, without limiting the generality of the foregoing, the times when contributions shall be credited under this Section 3 and the manner of allocating gains and losses of Accounts.
3.5No Actual Investment. Investment Funds are used only to measure hypothetical gains and losses. They do not represent actual investments made for a Participant. A Participant’s Account is only a bookkeeping entry, and the Participant remains an unsecured creditor of the Employer.
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SECTION 4
VESTING OF ACCOUNT
VESTING OF ACCOUNT
All Participants’ Accounts and subaccounts shall be 100% vested at all times.
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SECTION 5
PAYMENT
PAYMENT
5.1Participant Election of Time and Form of Payment. Each Plan Year, at the time of the Participant's deferral election(s), a Participant may separately elect, with respect to (i) Base Salary deferrals and any associated Employer Matching Credits, and (ii) Annual Incentive deferrals (if any) for such Plan Year, (a) the time of payment in accordance with Section 5.2 and (b) the form of payment in accordance with Section 5.3. A Participant may elect different payment dates and different forms of payment for each of these two contribution sources.
5.2Time of Payment. A Participant may elect each year to have the separate portions of the Participant’s deferrals as described in Section 5.1 paid on the earlier of: (a) a specific year in the future, or (b) Separation from Service. If the Participant fails to make an election, or if the election is ineffective, payment will be made upon Separation from Service.
5.2.1 Scheduled Future Date. If payment is made because the Participant elected a specific future year and that year occurs before the Participant’s Separation from Service, payment will be made in a lump sum on January 31 of the elected year.
5.2.2 Separation From Service. If payment is made because of the Participant’s Separation from Service, payment will be made, or will begin, on the first January 31 or July 31 following the six-month anniversary of the Participant’s Separation from Service.
Following a Participant’s Separation from Service, the Participant’s only remaining interest in the Plan is the right to receive payment of the Participant’s Account as provided in this Section, adjusted from time to time as provided in Section 3. A Participant is not required to apply to receive payment.
5.3Form of Payment. Payment will be in a lump sum for those Participants who choose to have payment made pursuant to Section 5.2.1, above. Participants choosing to be paid due to their Separation from Service under Section 5.2.2, above, may choose to have their account paid as follows:
5.3.1Term Certain Installments. In a series of installments payable over 10 years. The amount of the annual installments shall be determined by dividing the amount of the account as of January or July, according to the distribution timing of Section 5.2 above, as of which the installment is being paid by the number of remaining installments to be paid (including the payment being determined).
5.3.2Lump Sum. In a single lump sum cash payment.
5.3.3Default. If a Participant elects to have the Participant’s Account paid on Separation from Service but fails to make an election under this Section 5.3 or if such election is for any reason ineffective, the Participant shall be deemed to have elected a lump sum form of payment.
5.4Small Amounts. If, as of the last day of the month in which occurs the earlier of a Participant’s death or Separation from Service, the Participant’s Account balance under this Plan is less than $50,000, then, notwithstanding any election by the Participant under Section 5.3, the Participant
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shall be deemed to have elected to have the Participant's Account paid in a single lump sum payment within the 90-day period following such death or Separation from Service, as applicable.
5.5Subsequent Distribution Election. A Participant may change a prior distribution election as to the time or form of payment of the part of their Account that existed on December 31, 2008, by making a Subsequent Distribution Election, provided that such election satisfies all of the following requirements:
5.5.1The new distribution election may not accelerate the time or schedule of any distribution, except as provided in Code Section 409A and the regulations thereunder;
5.5.2The new distribution election is made at least 12 months prior to the date the first payment amount is scheduled to be distributed;
5.5.3The new distribution election must delay payment of such Participant’s Account (or such part thereof that relates to the election) for a period of at least 5 years after such payment would otherwise have been made; and
5.5.4If the election changes a Scheduled Future Date election under Section 5.2.1, such election is made at least 12 months prior to the Scheduled Future Date that is to be changed.
5.6Transitional Elections. During 2008, certain Participants were permitted to make new elections regarding the time and form of payment of their Account, subject to the following rules: (a) such elections were required to be made no later than December 31, 2008, (b) such elections could not change a payment that would otherwise have become payable in 2008 or cause payments to be made in 2008 that would otherwise be paid at a later date, and (c) such elections were made pursuant to such administrative rules as the Principal Sponsor prescribed. Any Participant who failed to make a new payment election in 2008 was deemed to have elected to have the Participant’s Account paid pursuant to the Participant’s election(s) on file with the Plan Administrator prior to the transitional election described in this Section.
5.7Payment on Death or Change in Control. Notwithstanding the payment elections described in Sections 5.2 and 5.3, a Participant's Account shall be subject to the following rules in the event of the Participant's death or a Change in Control:
5.7.1Death. Payment of the Participant’s Account shall be made to the Participant’s Beneficiary in a single lump sum cash payment within the 90-day period following the Participant’s death.
5.7.2Change in Control. A Change in Control shall not, by itself, trigger payment of a Participant's Account if the Plan is assumed, continued, or replaced by the acquiring entity or another employer following the transaction. In such case, the Participant's Account shall continue to be maintained and distributed in accordance with the Participant's existing elections and the terms of this Plan. If the Plan is not assumed, continued, or replaced, the Participant's Account shall be paid in a single cash lump sum within 90 days following the Change in Control, in a manner consistent with Code §409A and Treasury Regulation §1.409A-3(i)(5).
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5.8Payment to Beneficiary. If a Participant dies before the Participant’s Account has been fully distributed, any remaining unpaid balance of the Participant’s Account shall be paid to the Participant’s Beneficiary in a single lump sum cash payment within the 90-day period following the Participant’s death, regardless of whether installment payments had commenced before the Participant’s death.
5.9Withholding of Taxes. The benefits payable under this Plan shall be subject to the deduction of any federal, state, or local income taxes, Federal Insurance Contributions Act (FICA), FUTA or other taxes that are required to be withheld from such payments by applicable laws and regulations.
5.10Acceleration of Payments. Notwithstanding the preceding provisions of this Section 5, the Principal Sponsor, in its sole discretion, may accelerate payment of all or a portion of a Participant’s Account only to the extent permitted under Code Section 409A and Treasury Regulation §1.409A-3(j)(4). Any accelerated payment made under this Section shall reduce any payment otherwise payable under the Plan at a later date. Permitted accelerations may include, without limitation, the following:
5.10.1Financial Hardship Distribution. Upon receipt of an application for a Financial Hardship distribution, the Principal Sponsor shall administer and interpret this Section in a manner consistent with Code Section 409A and the Treasury Regulations thereunder. A Participant shall be eligible for a distribution only upon the occurrence of an unforeseeable emergency, as defined under Code Section 409A and applicable Treasury Regulations, and only to the extent permitted thereunder. If a Financial Hardship distribution is permitted, distribution of the amount reasonably necessary to satisfy the emergency need shall be made in a single lump sum payment as soon as administratively feasible.
5.10.2Payment of Employment Taxes or Income Taxes. Payments may be made at the time required by applicable law, for the payment or withholding of FICA tax imposed under Code §3101, §3121(a) and §3121(v)(2) or federal, state, local or foreign tax obligations arising from participation in the Plan provided distributions are limited to the amounts of such tax obligations.
5.10.3Payment upon Income Inclusion under Code §409A. If this Plan fails to meet the requirements of Code §409A, the amount of a Participant’s Account that is required to be included in the income of the affected Participant due to such failure shall be paid to such Participant in a single lump sum.
5.10.4Termination of Plan. Each Participant’s Account shall be paid to the Participant upon termination of the Plan to the extent provided in Section 7.
5.10.5Disability. A Participant shall be entitled to payment of the Participant's Account upon the Participant's Disability. A Participant will be considered Disabled if the Participant has been receiving benefits under the Employer's long-term disability program for at least six (6) consecutive months and the Plan Administrator determines that the Participant satisfies the disability requirements of Code Section 409A and the Treasury Regulations thereunder.
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5.11Application for Payment. The Administrator may prescribe from time to time the information to be submitted by a Participant or Beneficiary of a deceased Participant in connection with commencing a distribution from the Plan.
5.12Rehired Employee. If a Participant has a Separation from Service and payments in the installment method have begun, such installments shall not be suspended if such individual is subsequently reemployed by the Employer.
5.13Designation of Beneficiaries.
5.13.1 Right to Designate. Each Participant may designate, in a manner prescribed by the Principal Sponsor and filed with or otherwise received by the Principal Sponsor, one or more primary Beneficiaries or contingent Beneficiaries to receive all or a specified portion of the Participant's Account upon the Participant's death. The Participant may change or revoke any such designation from time to time without notice to or consent of any Beneficiary. No such designation, change, or revocation shall be effective unless made by the Participant and received by the Principal Sponsor during the Participant's lifetime.
5.13.2 Failure of Designation. If no valid Beneficiary designation is in effect at the Participant’s death, or if no designated Beneficiary survives the Participant, the Participant’s Account will be paid to the Participant’s estate or per court order.
5.13.3 Special Rules. Unless the Participant has otherwise specified in the Participant's Beneficiary designation, the following rules shall apply:
(a)If the Principal Sponsor does not receive sufficient evidence that a Beneficiary survived the Participant, the Beneficiary shall be treated as not having survived the Participant.
(b)Beneficiaries shall be determined as of the Participant's death. If a Beneficiary survives the Participant but dies before receiving all amounts payable under the Plan, any remaining amounts shall be paid to the Beneficiary's estate or legal representative.
(c)The Principal Sponsor may rely on the most recent valid Beneficiary designation received during the Participant's lifetime. The Participant is responsible for reviewing and updating any Beneficiary designation to reflect changes in personal circumstances, including marriage, divorce, dissolution, annulment, or other estate planning changes. The Principal Sponsor shall have no obligation to determine whether a Beneficiary designation reflects the Participant's current marital status, estate plan, or intent.
The Principal Sponsor shall be the sole judge of the content, interpretation and validity of any Beneficiary designation.
5.13.4 No Spousal Rights. No spouse or surviving spouse of a Participant and no person designated to be a Beneficiary shall have any rights or interest in the benefits accumulated under this Plan including, but not limited to, the right to be the sole Beneficiary or to consent to the designation of Beneficiaries (or the changing of designated Beneficiaries) by the Participant.
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5.14 Payment Obligations of Participating Employers. Payment of distributions from this Plan shall be made only by the Employer, which last employed the Participant before payments commence, provided, however, that each other Employer shall reimburse the paying Employer for benefits accrued by the Participant during the period (if any) that the Participant was employed by them.
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SECTION 6
UNFUNDED PLAN
UNFUNDED PLAN
6.1Establishment of Trust. Benefits under this Plan constitute only an unsecured promise by the Employer to make payments. A Participant shall have no lien, prior claim, security interest, or other interest in any property of the Employer. The Employer is not required to establish or maintain any trust, fund, or account to provide Plan benefits, other than a bookkeeping account or reserve. If a trust, fund, or other arrangement is established, its assets shall remain the sole and exclusive property of the Employer.
6.2Funding and Location of Trust. Any trust established by the Employer for purposes of paying benefits under this Plan, and the taxation of any assets held in such trust on behalf of Participants, shall be subject to the requirements of Code §409A, including (a) the rules pertaining to offshore funding set forth in Code §409A(b)(1), (b) the transfers of assets for the benefit of covered employees (as defined in Code §409A(b)(3)(d)(ii)) when a defined benefit pension plan of the Employer is in a restricted period, and (c) the restriction of assets in connection with a change in the Employer’s financial health under Code §409A(b)(2).
6.3Interrelationship of the Plan and the Trust. The provisions of the Plan shall govern the rights of a Participant or Beneficiary to receive distributions pursuant to the Plan. The provisions of the Trust (if any) shall govern the rights of the Employer, the Participants, and the creditors of the Employer relative to any property of the Employer set aside therein. The Employer shall at all times prior to the Plan’s termination remain liable to carry out its responsibilities under the Plan.
6.4Distributions from the Trust. The Employers’ obligations under the Plan may be satisfied with assets of the Trust (if any) distributed pursuant to the terms thereof, and any such distribution shall reduce the Employers’ obligations under the Plan. Alternatively, the obligations under the Plan may be satisfied by direct payment from the Employer’s general assets, and reimbursement from the Trust.
6.5Spendthrift Provision. No Participant or Beneficiary shall have any interest in any Account or Trust that can be transferred nor shall any Participant or Beneficiary have any power to anticipate, alienate, dispose of, pledge or encumber the same while in the possession or control of the Employer or the Trustee.
Notwithstanding the foregoing, this Section shall not prevent the Employer from complying with a domestic relations order deemed by the Principal Sponsor to be enforceable against the Plan, or from exercising, in its discretion, any applicable powers or options granted to it upon the occurrence of a Participant’s Separation from Service, as such powers or options may be conferred by any applicable provision of this Plan.
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SECTION 7
AMENDMENT AND TERMINATION
AMENDMENT AND TERMINATION
7.1Amendment. The Plan may be amended at any time and from time to time by the Governance, Compensation, and Nominating Committee of the Principal Sponsor (the “GCN Committee”). In addition, the Principal Sponsor’s Chief Executive Officer, Chief Financial Officer and Chief Human Resources Officer are each hereby delegated the authority to amend the Plan for any changes not pertaining to setting or modifying compensation of any “officer” as defined in Rule 16a-1(f) of the Securities and Exchange Act of 1934. Any such amendment may be retroactive, prospective or both. No such amendment of the Plan document or termination of the Plan, however, shall reduce a Participant's Account earned as of the date of such amendment unless the Participant so affected consents in writing to the amendment or such amendment is deemed necessary by the Employer to affect the intended purposes of this Plan and/or comply with applicable law. Any such amendment shall be communicated to the Employers participating in the Plan. Each Employer reserves the right to withdraw from participation in the Plan, but until such withdrawal occurs, they shall be bound by the Plan as originally established and as amended from time to time.
7.2Termination. The GCN Committee of the Principal Sponsor and the Principal Sponsor reserve the right to discontinue benefit accruals at any time. The Employer or Principal Sponsor also reserves the right to cause an acceleration of the time and form of a Plan payment where the acceleration of such payment is made in accordance with one of the following provisions:
7.2.1Dissolution or Bankruptcy. At the discretion of the Employer within 12 months of a corporate dissolution taxed under Code §331 or with the approval of a bankruptcy court pursuant to 11 U.S.C. §503(b)(1)(A), provided that Plan benefits are included in the Participants’ gross incomes in the latest of the following years (or, if earlier, the Participants’ respective tax year in which the benefits are actually or constructively received): (i) the first calendar year in which the Plan termination and liquidation occurs; (ii) the calendar year in which the amount is no longer subject to a substantial risk of forfeiture; or (iii) the first calendar year in which payment is administratively practicable.
7.2.2Discretionary Termination. A termination of the Plan that does not occur proximate to a downturn in the financial health of the Employer; provided that (a) all other arrangements sponsored by the Employer that would be aggregated with this arrangement under Treas. Reg. §1.409A-1(c) are also terminated (such aggregation being determined by assuming that all Participants have a benefit under any such other arrangement); (b) no payments in liquidation of the Plan, other than payments that would have been made under this Plan had the termination not occurred, are made from the Plan within 12 months of the date the Employer has taken all necessary action to irrevocably terminate and liquidate this Plan (the “Termination Date”); (c) all benefits are fully distributed within 24 months of the Termination Date; and (d) the Employer does not adopt a new arrangement that would be aggregated under Treas. Reg. §1.409A-1(c) with this Plan (such aggregation being determined by assuming that all Participants will have a benefit under any new arrangement) within 3 years following the Termination Date.
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SECTION 8
DETERMINATIONS – RULES AND REGULATIONS
DETERMINATIONS – RULES AND REGULATIONS
8.1Determinations. The Principal Sponsor shall make such determinations as may be required from time to time in the administration of the Plan. The Principal Sponsor shall have the discretionary authority and responsibility to interpret and construe the Plan Statement and to determine all factual and legal questions under the Plan, including but not limited to the entitlement of Participants and Beneficiaries, and the amounts of their respective interests. Each interested party may act and rely upon all information reported to them hereunder and need not inquire into the accuracy thereof, nor be charged with any notice to the contrary.
8.2Rules and Regulations. The Principal Sponsor hereof may adopt any rule not in conflict or at variance with the provisions of this Plan.
8.3Method of Executing Instruments. Information to be supplied or written notices to be made or consents to be given by the Principal Sponsor pursuant to any provision of this Plan Statement may be signed in the name of the Principal Sponsor by any officer who has been authorized to make such certification or to give such notices or consents.
8.4Claims Procedure. A person who believes they are entitled to benefits under the Plan may submit a written claim to the Principal Sponsor or its delegate. The Principal Sponsor or its delegate will review the claim and provide a written decision within 90 days after receiving the claim, unless special circumstances require additional time, in which case the claimant will be notified of the extension.
If a claim is denied in whole or in part, the written denial will state the specific reason for the denial, identify the Plan provisions on which the denial is based, describe any additional information needed to support the claim, and explain the appeal process.
A claimant may appeal a denied claim by submitting a written appeal within 60 days after receiving the denial. The claimant may submit written comments, documents, records, and other information relating to the claim. The Principal Sponsor or its delegate will provide a written decision on appeal within 60 days after receiving the appeal, unless special circumstances require additional time.
The decision on appeal will be final and binding, subject to the claimant’s right to bring an action under ERISA Section 502(a). No legal action may be brought unless the claimant first exhausts the claims and appeal procedures under this Section.
8.5Information Furnished by Participants. Neither the Principal Sponsor nor the Committee shall be liable or responsible for any error in the computation of the Account of a Participant resulting from any misstatement of fact made by the Participant, directly or indirectly, to the Principal Sponsor, where such misstatement is used (directly or indirectly) in determining the Participant's Account. The Principal Sponsor shall not be obligated or required to increase the Account of such Participant, which, on discovery of the misstatement, is understated as a result of such misstatement of the Participant. However, the Account of any Participant that is overstated by reason of any such misstatement shall be reduced to the amount appropriate.
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SECTION 9
PLAN ADMINISTRATION
PLAN ADMINISTRATION
9.1Principal Sponsor.
9.1.1Officers. Except as hereinafter provided, functions generally assigned to the Principal Sponsor shall be discharged by its officers or delegated and allocated as provided herein.
9.1.2Chief Executive Officer. The Chief Executive Officer of the Principal Sponsor may delegate or redelegate and allocate and reallocate to a Committee such functions assigned to the Principal Sponsor as may from time to time be deemed advisable. The Committee has delegated the day-to-day administrative duties to the Executive Compensation Total Rewards Group of the Principal Sponsor. If no Committee has been created, references to the Committee herein refer to the Principal Sponsor’s officers or delegates.
9.1.3Governance, Compensation and Nominating Committee. Any decision required to be determined at the level of Board of Directors or Compensation Committee of the Principal Sponsor (whether by rule, regulation or charter) shall be determined within such Board or Compensation Committee, unless such decision making authority has been properly delegated under this Section.
9.1.4Majority Decisions. If there shall at any time be three (3) or more members of the Committee serving hereunder who are qualified to perform a particular act, the same may be performed in writing or in a meeting, on behalf of all, by a majority of those qualified, with or without the concurrence of the minority. No person who failed to join or concur in such act shall be held liable for the consequences thereof, except to the extent that liability is imposed under ERISA.
9.2Limitation on Authority.
9.3.1Generally. No action taken by any person, if authority to take such action has been delegated or redelegated to it, shall be the responsibility of any other person except as may be required by the provisions of ERISA. Except to the extent imposed by ERISA, no person shall have the duty to question whether any other fiduciary is fulfilling all of the responsibility imposed upon such other person by the Plan Statement or by ERISA.
9.3.2Trustee. If any trust is established, the responsibilities and obligations of the Trustee shall be strictly limited to those set forth in the agreement of trust. The Trustee shall have no authority or duty to determine or enforce payment of any Employer credit under the Plan or to determine the existence, nature or extent of any individual’s rights in the Trust Fund or under the Plan or question any determination made by the Principal Sponsor or the Committee regarding the same. Nor shall the Trustee be responsible in any way for the manner in which the Principal Sponsor, the Employer or the Committee carries out its responsibilities under this Plan Statement or, more generally, under the Plan. The Trustee shall give the Principal Sponsor notice of (and tender to the Principal Sponsor) the prosecution or defense of any litigation involving the Plan, the Trust Fund or other persons acting with respect to the Plan.
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9.3Administrator. The Principal Sponsor shall be the administrator for purposes of section 3(16)(A) of ERISA.
9.4Service of Process. In the absence of any designation to the contrary by the Principal Sponsor, Corporation Services Company is designated as the appropriate and exclusive agent for the receipt of service of process directed to the Plan in any legal proceeding, including arbitration, involving the Plan.
9.5Administrative Expenses. The reasonable expenses of administering the Plan shall be payable out of the Trust Fund, if any, except to the extent that the Employer, in its discretion, directly pays the expenses.
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SECTION 10
DISCLAIMERS
DISCLAIMERS
10.1Term of Employment. Participation in this Plan and the availability of benefits under the Plan do not constitute a term or condition of employment. The Employer reserves the right to amend or terminate the Plan at any time. Nothing in this Plan gives any employee the right to continued employment with the Employer.
10.2Source of Payment. Neither the Employer nor any of its officers nor any member of its Committee or the Board of Directors may in any way secure or guarantee the payment of any benefit or amount which may become due and payable hereunder to any Participant or to any Beneficiary or to any creditor of a Participant or a Beneficiary. Each Participant, Beneficiary or other person entitled at any time to payments hereunder shall look solely to the assets of the Employer employing such Participant for such payments or to the Accounts distributed to any Participant or Beneficiary, as the case may be for such payments. In each case where Accounts shall have been distributed to a former Participant or a Beneficiary or to the person or any one of a group of persons entitled jointly to the receipt thereof and which purports to cover in full the benefit hereunder, such former Participant or Beneficiary, or such person or persons, as the case may be, shall have no further right or interest in the other assets of the Employer. Neither the Employer nor any of its officers nor any member of its Board of Directors shall be under any liability or responsibility for failure to effect any of the objectives or purposes of the Plan by reason of the insolvency of the Employer.
10.3Delegation. The Employer, and its officers and the members of its Board of Directors and the Committee shall not be liable for an act or omission of another person with regard to a responsibility that has been allocated to or delegated to such other person pursuant to the terms of this Plan Statement or pursuant to procedures set forth in this Plan Statement.
__________________, 2026
XCEL ENERGY INC.
By________________________________
Its________________________________
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ADDENDUM A
DESIGNATED EMPLOYERS AND DESIGNATED AFFILIATES
DESIGNATED EMPLOYERS AND DESIGNATED AFFILIATES
Eloigne
Northern States Power Company Minnesota
Public Service Company of Colorado
Southwestern Public Service Company
Northern States Power Company Wisconsin
Xcel Energy Services Inc.
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Exhibit 31.01
CERTIFICATION
I, Robert C. Frenzel, certify that:
1.I have reviewed this report on Form 10-Q of Xcel Energy Inc. (a Minnesota corporation);
2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c.Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
d.Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
Date: July 30, 2026
| /s/ ROBERT C. FRENZEL | |||||
| Robert C. Frenzel | |||||
| President, Chief Executive Officer and Director | |||||
| (Principal Executive Officer) | |||||
1
Exhibit 31.02
CERTIFICATION
I, Brian J. Van Abel, certify that:
1.I have reviewed this report on Form 10-Q of Xcel Energy Inc. (a Minnesota corporation);
2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c.Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
d.Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
Date: July 30, 2026
| /s/ BRIAN J. VAN ABEL | |||||
| Brian J. Van Abel | |||||
| Executive Vice President, Chief Financial Officer | |||||
| (Principal Financial Officer) | |||||
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Exhibit 32.01
OFFICER CERTIFICATION
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
In connection with the Quarterly Report of Xcel Energy Inc. (Xcel Energy) on Form 10-Q for the quarter ended June 30, 2026, as filed with the SEC on the date hereof (Form 10-Q), each of the undersigned officers of Xcel Energy certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to such officer’s knowledge:
(1)The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of Xcel Energy as of the dates and for the periods expressed in the Form 10-Q.
Date: July 30, 2026
| /s/ ROBERT C. FRENZEL | |||||
| Robert C. Frenzel | |||||
| President, Chief Executive Officer and Director | |||||
| (Principal Executive Officer) | |||||
| /s/ BRIAN J. VAN ABEL | |||||
| Brian J. Van Abel | |||||
| Executive Vice President, Chief Financial Officer | |||||
| (Principal Financial Officer) | |||||
The foregoing certification is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of the Report or as a separate disclosure document.
A signed original of this written statement required by Section 906, or other document authenticating, acknowledging or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to Xcel Energy and will be retained by Xcel Energy and furnished to the SEC or its staff upon request.
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