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TXNM ENERGY INC filed this 10-K on Feb 28, 2025

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TXNM ENERGY INC - 10-K - 20250228 - FINANCIAL_STATEMENTS

ITEM 8.FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

INDEX


						Page
Management’s Annual Reports on Internal Control Over Financial Reporting						2
Reports of Independent Registered Public Accounting Firm (PCAOB ID 185)						5
Financial Statements:
TXNM Energy, Inc. and Subsidiaries
Consolidated Statements of Earnings						11
Consolidated Statements of Comprehensive Income						12
Consolidated Statements of Cash Flows						13
Consolidated Balance Sheets						15
Consolidated Statements of Changes in Equity						17
Public Service Company of New Mexico and Subsidiaries
Consolidated Statements of Earnings						18
Consolidated Statements of Comprehensive Income						19
Consolidated Statements of Cash Flows						20
Consolidated Balance Sheets						22
Consolidated Statements of Changes in Equity						24
Texas-New Mexico Power Company and Subsidiaries
Consolidated Statements of Earnings						25

Consolidated Statements of Cash Flows						26
Consolidated Balance Sheets						28
Consolidated Statements of Changes in Common Stockholder’s Equity						30
Notes to Consolidated Financial Statements						31
Supplementary Data:

Schedule I - Condensed Financial Information of Parent Company						112
Schedule II - Valuation and Qualifying Accounts						115

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MANAGEMENT’S ANNUAL REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management of TXNM Energy, Inc. and subsidiaries (“TXNM”) is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934, as amended.

Management assessed the effectiveness of TXNM’s internal control over financial reporting based on the Internal Control – Integrated Framework (2013) set forth by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the assessment performed, management concludes that TXNM’s internal control over financial reporting was effective as of December 31, 2024.

The effectiveness of our internal control over financial reporting as of and for the year ended December 31, 2024 has been audited by KPMG LLP, an independent registered public accounting firm, as stated in their audit report which is included herein.


/s/ Patricia K. Collawn
Patricia K. Collawn,
Chairman and Chief Executive Officer

/s/ Elisabeth A. Eden
Elisabeth A. Eden,
Senior Vice President and Chief Financial Officer

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MANAGEMENT’S ANNUAL REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management of Public Service Company of New Mexico and subsidiaries (“PNM”) is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934, as amended.

Management assessed the effectiveness of PNM’s internal control over financial reporting based on the Internal Control – Integrated Framework (2013) set forth by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the assessment performed, management concludes that PNM’s internal control over financial reporting was effective as of December 31, 2024.


/s/ Joseph D. Tarry
Joseph D. Tarry,
President and Chief Executive Officer

/s/ Elisabeth A. Eden
Elisabeth A. Eden,
Senior Vice President and Chief Financial Officer

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MANAGEMENT’S ANNUAL REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management of Texas-New Mexico Power Company and subsidiaries (“TNMP”) is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934, as amended.

Management assessed the effectiveness of TNMP’s internal control over financial reporting based on the Internal Control – Integrated Framework (2013) set forth by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the assessment performed, management concludes that TNMP’s internal control over financial reporting was effective as of December 31, 2024.


/s/ Joseph D. Tarry
Joseph D. Tarry,
Chief Executive Officer

/s/ Elisabeth A. Eden
Elisabeth A. Eden,
Senior Vice President and Chief Financial Officer

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Report of Independent Registered Public Accounting Firm

To the Stockholders and Board of Directors

TXNM Energy, Inc.:

Opinions on the Consolidated Financial Statements and Internal Control Over Financial Reporting

We have audited the accompanying consolidated balance sheets of TXNM Energy, Inc. and subsidiaries (the Company) as of December 31, 2024 and 2023, the related consolidated statements of earnings, comprehensive income, changes in equity, and cash flows for each of the years in the three-year period ended December 31, 2024, and the related notes and financial statement Schedule I - Condensed Financial Information of Parent Company and Schedule II - Valuation and Qualifying Accounts (collectively, the consolidated financial statements). We also have audited the Company’s internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2024, in conformity with U.S. generally accepted accounting principles. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2024 based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

Basis for Opinions

The Company’s management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s consolidated financial statements and an opinion on the Company’s internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.

Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control Over Financial Reporting

A company’s internal control over financial reporting is a process designed 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. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the

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company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Critical Audit Matter

The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of a critical audit matter does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

Evaluation of regulatory assets and liabilities

As discussed in Notes 1, 13, and 17 to the consolidated financial statements, the Company accounts for their regulated operations in accordance with Financial Accounting Standards Board Accounting Standard Codification Topic 980, Regulated Operations (ASC Topic 980). Pursuant to the requirements of ASC Topic 980, the financial statements of a rate-regulated enterprise reflect the actions of regulators. The Company capitalizes, as regulatory assets, incurred and accrued costs that are probable of recovery in future electric rates. In addition, obligations to refund previously collected revenue or to spend revenue collected from customers on future costs are recorded as regulatory liabilities. The Company is subject to comprehensive federal, state and local regulation and legislation, including regulations promulgated by the New Mexico Public Regulation Commission, Public Utility Commission of Texas, and the Federal Energy Regulatory Commission.

We have identified the evaluation of regulatory assets and liabilities as a critical audit matter. This was due to the extent of audit effort required in the evaluation of regulatory assets and liabilities in each of the relevant jurisdictions.

The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls over the Company’s regulatory accounting process, including controls related to the Company’s application of ASC Topic 980 in each jurisdiction and the Company’s calculation and review of regulatory assets and liabilities. We selected regulatory assets and liabilities and assessed the Company’s application of ASC Topic 980 in the relevant jurisdiction by evaluating the underlying orders, statutes, rulings, memorandums, filings or publications issued by the respective regulators. We selected a sample of the regulatory assets and liabilities activity and using the methodologies approved by the relevant regulatory commissions, recalculated the activity and agreed the data used in the calculations to the Company’s underlying books and records. We compared the amounts calculated by the Company to the amounts recorded in the consolidated financial statements.

/s/ KPMG LLP

We have served as the Company’s auditor since 2013.

New York, New York

February 28, 2025

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Report of Independent Registered Public Accounting Firm

To the Stockholders and Board of Directors

Public Service Company of New Mexico:

Opinion on the Consolidated Financial Statements

We have audited the accompanying consolidated balance sheets of Public Service Company of New Mexico and subsidiaries (the Company) as of December 31, 2024 and 2023, the related consolidated statements of earnings, comprehensive income, changes in equity, and cash flows for each of the years in the three-year period ended December 31, 2024, and the related notes and financial statement Schedule II - Valuation and Qualifying Accounts (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2024, in conformity with U.S. generally accepted accounting principles.

Basis for Opinion

These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matter

Evaluation of regulatory assets and liabilities

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/s/ KPMG LLP

We have served as the Company’s auditor since 2013.

New York, New York

February 28, 2025

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Report of Independent Registered Public Accounting Firm

To the Stockholder and Board of Directors

Texas‑New Mexico Power Company:

Opinion on the Consolidated Financial Statements

We have audited the accompanying consolidated balance sheets of Texas-New Mexico Power Company and subsidiaries (the Company) as of December 31, 2024 and 2023, the related consolidated statements of earnings, changes in common stockholder’s equity, and cash flows for each of the years in the three-year period ended December 31, 2024, and the related notes and financial statement Schedule II - Valuation and Qualifying Accounts (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2024, in conformity with U.S. generally accepted accounting principles.

Basis for Opinion

We conducted our audits in accordance with the standards of the PCAOB and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Critical Audit Matter

Evaluation of regulatory assets and liabilities

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The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls over the Company’s regulatory accounting process, including controls related to the Company’s application of ASC Topic 980 and the Company’s calculation and review of regulatory assets and liabilities. We selected regulatory assets and liabilities and assessed the Company’s application of ASC Topic 980 by evaluating the underlying orders, statutes, rulings, memorandums, filings or publications issued by the Public Utility Commission of Texas. We selected a sample of the regulatory assets and liabilities activity and using the methodologies approved by the Public Utility Commission of Texas, recalculated the activity and agreed the data used in the calculations to the Company’s underlying books and records. We compared the amounts calculated by the Company to the amounts recorded in the consolidated financial statements.

/s/ KPMG LLP

We have served as the Company’s auditor since 2013.

New York, New York

February 28, 2025

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TXNM ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF EARNINGS


	Year Ended December 31,
	2024		2023		2022
	(In thousands, except per share amounts)





Electric Operating Revenues	$	1,971,199	$	1,939,198	$	2,249,555
Operating Expenses:
Cost of energy	583,984		802,261		987,941
Administrative and general	247,116		227,900		227,149
Energy production costs	93,748		91,610		147,347
Regulatory disallowances	8,980		71,923		832
Depreciation and amortization	384,925		319,503		304,853
Transmission and distribution costs	98,380		98,721		94,684
Taxes other than income taxes	100,580		95,940		92,989
Total operating expenses	1,517,713		1,707,858		1,855,795
Operating income	453,486		231,340		393,760
Other Income and Deductions:
Interest income	23,537		21,963		16,095
Gains (losses) on investment securities	26,851		19,246		(78,357)
Other income	28,621		24,204		21,601



Other (deductions)	(24,189)		(15,869)		(13,881)
Net other income and (deductions)	54,820		49,544		(54,542)
Interest Charges	228,066		190,355		127,908
Earnings before Income Taxes	280,240		90,529		211,310
Income Taxes (Benefits)	21,518		(16,350)		26,130
Net Earnings	258,722		106,879		185,180
(Earnings) Attributable to Valencia Non-controlling Interest	(16,040)		(18,533)		(15,122)
Preferred Stock Dividend Requirements of Subsidiary	(528)		(528)		(528)
Net Earnings Attributable to TXNM	$	242,154	$	87,818	$	169,530
Net Earnings Attributable to TXNM per Common Share:
Basic	$	2.67	$	1.02	$	1.97
Diluted	$	2.67	$	1.02	$	1.97

The accompanying notes, as they relate to TXNM, are an integral part of these consolidated financial statements.

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TXNM ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Net Earnings	$	258,722	$	106,879	$	185,180
Other Comprehensive Income:
Unrealized Gains on Available-for-Sale Debt Securities:
Net increase (decrease) in unrealized holding gains arising during the period, net of income tax (expense) benefit of $225, $(2,928), and $490	(660)		8,601		(1,438)
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $3,330, $1,828, and $972	(9,778)		(5,371)		(2,855)
Pension Liability Adjustment:
Experience gains (losses), net of income tax (expense) benefit of $815, $(353), and $1,159	(2,395)		1,036		(3,406)
Reclassification adjustment for amortization of experience losses recognized as net periodic benefit cost, net of income tax (benefit) of $(1,236), $(1,212), and $(1,804)	3,630		3,564		5,300
Fair Value Adjustment for Cash Flow Hedges:
Change in fair market value, net of income tax (expense) of $3,876, $3,933, and $(3,121)	(11,384)		(11,550)		9,164
Reclassification adjustment for (gains) losses included in net earnings, net of income tax expense (benefit) of $(2,629), $(2,359), and $299	7,719		6,928		(877)
Total Other Comprehensive Income (Loss)	(12,868)		3,208		5,888
Comprehensive Income	245,854		110,087		191,068
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(16,040)		(18,533)		(15,122)
Preferred Stock Dividend Requirements of Subsidiary	(528)		(528)		(528)
Comprehensive Income Attributable to TXNM	$	229,286	$	91,026	$	175,418

The accompanying notes, as they relate to TXNM, are an integral part of these consolidated financial statements.

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TXNM ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	258,722	$	106,879	$	185,180
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	423,010		353,692		341,123
Deferred income tax expense (benefit)	43,050		(13,509)		24,533




(Gain) on sale of NMRD	(4,449)		—		—
(Gains) losses on investment securities	(26,851)		(19,246)		78,357


Stock based compensation expense	9,480		7,190		7,825
Regulatory disallowances	8,980		71,923		832
Allowance for equity funds used during construction	(17,887)		(14,978)		(13,799)
Other, net	4,165		804		2,377
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(13,349)		53,229		(73,099)
Materials, supplies, and fuel stock	(33,804)		(31,301)		(8,528)
Other current assets	31,967		(52,225)		17,159
Other assets	(83,541)		(25,820)		5,002
Accounts payable	10,021		(33,536)		47,568
Accrued interest and taxes	5,114		17,526		9,205
Other current liabilities	(106,374)		125,580		(28,516)

Other liabilities	(94)		4,963		(27,935)
Net cash flows from operating activities	508,160		551,171		567,284
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(1,247,041)		(1,075,812)		(912,557)
Proceeds from sale of plant assets (Note 8)	2,840		32,654		—
Proceeds from sales of investment securities	707,338		574,199		526,448
Purchases of investment securities	(756,805)		(593,241)		(564,912)



Proceeds from sale of NMRD	116,936		—		—

Investments in NMRD	(12,550)		(26,250)		—



Other, net	14,910		44		674
Net cash flows used in investing activities	(1,174,372)		(1,088,406)		(950,347)

The accompanying notes, as they relate to TXNM, are an integral part of these consolidated financial statements.

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TXNM ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Cash Flows From Financing Activities:


Revolving credit facilities borrowings	$	2,892,200	$	2,358,900	$	1,829,500
Revolving credit facilities repayments	(2,544,800)		(2,329,000)		(1,660,200)
Long-term borrowings	1,233,000		1,358,096		558,000
Repayment of long-term debt	(819,529)		(910,000)		(179,500)


Issuance of common stock	98,601		198,177		—

Awards of common stock	(8,460)		(9,646)		(7,980)


Dividends paid	(140,339)		(126,705)		(119,839)
Valencia’s transactions with its owner	(19,098)		(21,569)		(17,533)
Transmission interconnection and security deposit arrangements	92,272		49,807		96,550
Refunds paid under transmission interconnection and security deposit arrangements	(79,011)		(21,124)		(107,397)
Debt issuance costs and other, net	(20,482)		(9,836)		(5,564)
Net cash flows from financing activities	684,354		537,100		386,037

Change in Cash, Cash Equivalents, and Restricted Cash	18,142		(135)		2,974
Cash, Cash Equivalents, and Restricted Cash at Beginning of Year	3,943		4,078		1,104
Cash, Cash Equivalents, and Restricted Cash at End of Year	$	22,085	$	3,943	$	4,078

Restricted Cash Included in Other Current Assets and Other Deferred Charges on Consolidated Balance Sheets:
At beginning of period	$	1,728	$	—	$	—
At end of period	$	17,587	$	1,728	$	—

Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	207,972	$	155,273	$	118,485
Income taxes paid (refunded), net	$	(998)	$	1,505	$	(1,011)

Supplemental schedule of noncash investing and financing activities:
(Increase) decrease in accrued plant additions	$	10,728	$	(23,002)	$	4,455

The accompanying notes, as they relate to TXNM, are an integral part of these consolidated financial statements.

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TXNM ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS


	December 31,
	2024		2023
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	4,498	$	2,215
Accounts receivable, net of allowance for credit losses of $1,398 and $3,388	130,351		126,291
Unbilled revenues	69,176		64,072
Other receivables	37,236		76,509

Materials, supplies, and fuel stock	166,861		98,034
Regulatory assets	41,492		73,046

Prepaid assets	25,452		19,759
Income taxes receivable	7,684		6,697

Other current assets	16,086		8,920
Total current assets	498,836		475,543
Other Property and Investments:


Investment securities	475,524		444,408
Equity investment in NMRD	—		119,570
Other investments	259		171
Non-utility property, including financing leases	28,832		29,367
Total other property and investments	504,615		593,516
Utility Plant:
Plant in service, held for future use, and to be abandoned	10,697,774		9,701,180
Less accumulated depreciation and amortization	2,829,296		2,755,823
	7,868,478		6,945,357
Construction work in progress	495,976		589,834
Nuclear fuel, net of accumulated amortization of $28,245 and $35,840	72,554		74,671
Net utility plant	8,437,008		7,609,862
Deferred Charges and Other Assets:
Regulatory assets	962,003		914,381
Goodwill	278,297		278,297
Operating lease right-of-use assets, net of accumulated amortization	272,894		182,201

Other deferred charges	258,080		198,805
Total deferred charges and other assets	1,771,274		1,573,684
	$	11,211,733	$	10,252,605

The accompanying notes, as they relate to TXNM, are an integral part of these consolidated financial statements.

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TXNM ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS


	December 31,
	2024		2023
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Short-term debt	$	609,300	$	261,900
Current installments of long-term debt (includes $6,907 and $2,529 related to ETBC I)	611,603		280,169
Accounts payable	204,468		205,175
Customer deposits	6,533		6,237
Accrued interest and taxes	104,756		98,655
Regulatory liabilities	34,173		140,005
Operating lease liabilities	14,293		12,267

Dividends declared	36,889		35,085

Transmission interconnection arrangement liabilities	68,085		96,870
Other current liabilities	84,998		94,397
Total current liabilities	1,775,098		1,230,760
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $331,726 and $338,521 related to ETBC I)	4,311,765		4,241,642
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	899,392		845,280

Regulatory liabilities	748,738		771,317
Asset retirement obligations	244,618		245,531
Accrued pension liability and postretirement benefit cost	23,065		21,429
Operating lease liabilities	255,376		167,000

Other deferred credits	358,867		319,066
Total deferred credits and other liabilities	2,530,056		2,369,623
Total liabilities	8,616,919		7,842,025
Commitments and Contingencies (See Note 16)
Cumulative Preferred Stock of Subsidiary
without mandatory redemption requirements ($100 stated value; 10,000,000 shares authorized; issued and outstanding 115,293 shares)	11,529		11,529
Equity:
TXNM common stockholders’ equity:
Common stock (no par value; 200,000,000 and 120,000,000 shares authorized; issued and outstanding 92,659,335 and 90,200,384 shares)	1,724,444		1,624,823
Accumulated other comprehensive income (loss), net of income taxes	(75,708)		(62,840)
Retained earnings	887,649		787,110
Total TXNM common stockholders’ equity	2,536,385		2,349,093
Non-controlling interest in Valencia	46,900		49,958
Total equity	2,583,285		2,399,051
	$	11,211,733	$	10,252,605

The accompanying notes, as they relate to TXNM, are an integral part of these consolidated financial statements.

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TXNM ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY


	Attributable to TXNM								Non- controlling Interest in Valencia
							Total TXNM Common Stockholder’s Equity
	Common Stock		AOCI		Retained Earnings						Total Equity
	(In thousands)


Balance at December 31, 2021	$	1,429,257	$	(71,936)	$	810,203	$	2,167,524	$	55,405	$	2,222,929

Net earnings before subsidiary preferred stock dividends	—		—		170,058		170,058		15,122		185,180
Total other comprehensive income	—		5,888		—		5,888		—		5,888
Subsidiary preferred stock dividends	—		—		(528)		(528)		—		(528)
Dividends declared on common stock	—		—		(150,855)		(150,855)		—		(150,855)

Awards of common stock	(7,980)		—		—		(7,980)		—		(7,980)


Stock based compensation expense	7,825		—		—		7,825		—		7,825
Valencia’s transactions with its owner	—		—		—		—		(17,533)		(17,533)




Balance at December 31, 2022	1,429,102		(66,048)		828,878		2,191,932		52,994		2,244,926

Net earnings before subsidiary preferred stock dividends	—		—		88,346		88,346		18,533		106,879
Total other comprehensive income	—		3,208		—		3,208		—		3,208
Subsidiary preferred stock dividends	—		—		(528)		(528)		—		(528)
Dividends declared on common stock	—		—		(129,586)		(129,586)		—		(129,586)

Awards of common stock	(9,646)		—		—		(9,646)		—		(9,646)
Issuance of common stock	198,177		—		—		198,177		—		198,177
Stock based compensation expense	7,190		—		—		7,190		—		7,190
Valencia’s transactions with its owner	—		—		—		—		(21,569)		(21,569)


Balance at December 31, 2023	1,624,823		(62,840)		787,110		2,349,093		49,958		2,399,051



Net earnings before subsidiary preferred stock dividends	—		—		242,682		242,682		16,040		258,722
Total other comprehensive income (loss)	—		(12,868)		—		(12,868)		—		(12,868)
Subsidiary preferred stock dividends	—		—		(528)		(528)		—		(528)
Dividends declared on common stock	—		—		(141,615)		(141,615)		—		(141,615)

Awards of common stock	(8,460)		—		—		(8,460)		—		(8,460)
Issuance of common stock	98,601		—		—		98,601		—		98,601
Stock based compensation expense	9,480		—		—		9,480		—		9,480
Valencia’s transactions with its owner	—		—		—		—		(19,098)		(19,098)


Balance at December 31, 2024	$	1,724,444	$	(75,708)	$	887,649	$	2,536,385	$	46,900	$	2,583,285

The accompanying notes, as they relate to TXNM, are an integral part of these consolidated financial statements.

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Table of Contents

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED STATEMENTS OF EARNINGS


	Year Ended December 31,
	2024		2023		2022
	(In thousands)





Electric Operating Revenues	$	1,379,088	$	1,403,948	$	1,766,825
Operating Expenses:
Cost of energy	434,918		663,614		864,013
Administrative and general	226,560		206,650		204,846
Energy production costs	93,748		91,610		147,347
Regulatory disallowances	8,980		70,750		832
Depreciation and amortization	221,780		177,633		180,812
Transmission and distribution costs	61,302		61,725		58,278
Taxes other than income taxes	49,807		48,790		49,210
Total operating expenses	1,097,095		1,320,772		1,505,338
Operating income	281,993		83,176		261,487
Other Income and Deductions:
Interest income	23,454		21,355		14,816
Gains (losses) on investment securities	26,851		19,246		(78,357)
Other income	15,329		11,638		10,763
Other (deductions)	(4,140)		(10,881)		(9,418)
Net other income and (deductions)	61,494		41,358		(62,196)
Interest Charges	106,018		86,574		61,073
Earnings before Income Taxes	237,469		37,960		138,218
Income Taxes (Benefits)	29,217		(16,758)		19,198
Net Earnings	208,252		54,718		119,020
(Earnings) Attributable to Valencia Non-controlling Interest	(16,040)		(18,533)		(15,122)
Net Earnings Attributable to PNM	192,212		36,185		103,898
Preferred Stock Dividends Requirements	(528)		(528)		(528)
Net Earnings Available for PNM Common Stock	$	191,684	$	35,657	$	103,370

The accompanying notes, as they relate to PNM, are an integral part of these consolidated financial statements.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Net Earnings	$	208,252	$	54,718	$	119,020
Other Comprehensive Income:
Unrealized Gains on Available-for-Sale Debt Securities:
Net increase (decrease) in unrealized holding gains (losses) arising during the period, net of income tax (expense) benefit of $225, $(2,928), and $490	(660)		8,601		(1,438)
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $3,330, $1,828, and $972	(9,778)		(5,371)		(2,855)
Pension Liability Adjustment:
Experience gains (losses), net of income tax (expense) benefit of $815, $(353), and $1,159	(2,395)		1,036		(3,406)
Reclassification adjustment for amortization of experience losses recognized as net periodic benefit cost, net of income tax (benefit) of $(1,236), $(1,212), and $(1,804)	3,630		3,564		5,300



Total Other Comprehensive Income (Loss)	(9,203)		7,830		(2,399)
Comprehensive Income	199,049		62,548		116,621
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(16,040)		(18,533)		(15,122)
Comprehensive Income Attributable to PNM	$	183,009	$	44,015	$	101,499

The accompanying notes, as they relate to PNM, are an integral part of these consolidated financial statements.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	208,252	$	54,718	$	119,020
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	250,042		202,885		213,517
Deferred income tax expense (benefit)	41,903		(21,972)		29,487

(Gains) losses on investment securities	(26,851)		(19,246)		78,357

Regulatory disallowances	8,980		70,750		832

Allowance for equity funds used during construction	(13,043)		(9,832)		(9,323)
Other, net	4,459		3,485		3,758
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(11,295)		51,314		(60,743)
Materials, supplies, and fuel stock	(25,915)		(25,681)		(4,804)
Other current assets	19,943		(54,934)		17,956
Other assets	(33,013)		(20,956)		5,487
Accounts payable	8,135		(30,423)		48,868
Accrued interest and taxes	(3,041)		16,091		(19,574)
Other current liabilities	(99,353)		123,048		(41,876)

Other liabilities	(7,691)		4,588		(26,029)
Net cash flows from operating activities	321,512		343,835		354,933
Cash Flows From Investing Activities:
Utility plant additions	(682,412)		(565,080)		(433,459)
Proceeds from sale of plant assets (Note 8)	2,840		32,654		—
Proceeds from sales of investment securities	707,338		574,199		526,448
Purchases of investment securities	(756,805)		(593,241)		(564,912)




Other, net	14,885		7		439
Net cash flows used in investing activities	(714,154)		(551,461)		(471,484)

The accompanying notes, as they relate to PNM, are an integral part of these consolidated financial statements.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS


	Year ended December 31,
	2024		2023		2022
	(In thousands)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings	$	1,433,200	$	1,114,300	$	708,600
Revolving credit facilities repayments	(1,206,900)		(1,162,700)		(530,100)

Long-term borrowings	398,000		673,096		298,000
Repayment of long-term debt	(200,529)		(410,000)		(179,500)
Equity contribution from parent	55,000		—		—
Dividends paid	(51,529)		(528)		(154,028)
Valencia’s transactions with its owner	(19,098)		(21,569)		(17,533)
Transmission interconnection and security deposit arrangements	81,022		38,807		90,150
Refunds paid under transmission interconnection and security deposit arrangements	(74,161)		(17,624)		(93,247)
Debt issuance costs and other, net	(4,664)		(6,555)		(2,825)
Net cash flows from financing activities	410,341		207,227		119,517

Change in Cash, Cash Equivalents, and Restricted Cash	17,699		(399)		2,966
Cash, Cash Equivalents, and Restricted Cash at Beginning of Year	2,586		2,985		19
Cash, Cash Equivalents, and Restricted Cash at End of Year	$	20,285	$	2,586	$	2,985

Restricted Cash Included in Other Current Assets and Other Deferred Charges on Consolidated Balance Sheets:
At beginning of period	$	1,728	$	—	$	—
At end of period	$	17,587	$	1,728	$	—

Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	85,100	$	66,456	$	54,816
Income taxes paid (refunded), net	$	(4,058)	$	(5,338)	$	11,602

Supplemental schedule of noncash investing activities:
(Increase) decrease in accrued plant additions	$	25,955	$	(8,604)	$	(6,859)

The accompanying notes, as they relate to PNM, are an integral part of these consolidated financial statements.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED BALANCE SHEETS


	December 31,
	2024		2023
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	2,698	$	858
Accounts receivable, net of allowance for credit losses of $1,398 and $3,388	95,932		94,879
Unbilled revenues	52,983		46,925
Other receivables	24,174		51,975
Affiliate receivables	9,241		9,253
Materials, supplies, and fuel stock	142,510		81,572
Regulatory assets	36,224		72,996

Prepaid assets	14,746		9,941
Income taxes receivable	16,309		7,682

Other current assets	16,091		1,756
Total current assets	410,908		377,837
Other Property and Investments:

Investment securities	475,524		444,408
Other investments	184		69
Non-utility property, including financing leases	13,647		13,538
Total other property and investments	489,355		458,015
Utility Plant:
Plant in service, held for future use, and to be abandoned	6,797,493		6,151,510
Less accumulated depreciation and amortization	2,079,363		1,976,657
	4,718,130		4,174,853
Construction work in progress	328,403		490,178
Nuclear fuel, net of accumulated amortization of $28,245 and $35,840	72,554		74,671
Net utility plant	5,119,087		4,739,702
Deferred Charges and Other Assets:
Regulatory assets	857,310		838,727
Goodwill	51,632		51,632

Operating lease right-of-use assets, net of accumulated amortization	271,433		180,370
Other deferred charges	207,554		166,782
Total deferred charges and other assets	1,387,929		1,237,511
	$	7,407,279	$	6,813,065

The accompanying notes, as they relate to PNM, are an integral part of these consolidated financial statements.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED BALANCE SHEETS


	December 31,
	2024		2023
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:
Short-term debt	$	363,800	$	137,500

Current installments of long-term debt (includes $6,907 and $2,529 related to ETBC I)	560,637		200,222
Accounts payable	123,883		141,704
Affiliate payables	15,695		16,388
Customer deposits	6,533		6,237
Accrued interest and taxes	46,923		41,337
Regulatory liabilities	33,571		134,846
Operating lease liabilities	13,542		11,371

Dividends declared	132		132

Transmission interconnection arrangement liabilities	68,085		96,870
Other current liabilities	50,099		52,587
Total current liabilities	1,282,900		839,194
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $331,726 and $338,521 related to ETBC I)	1,898,955		2,061,558
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	756,218		684,037

Regulatory liabilities	518,701		565,021
Asset retirement obligations	243,663		244,633
Accrued pension liability and postretirement benefit cost	22,067		19,949
Operating lease liabilities	254,702		166,191

Other deferred credits	234,346		220,178
Total deferred credits and liabilities	2,029,697		1,900,009
Total liabilities	5,211,552		4,800,761
Commitments and Contingencies (See Note 16)
Cumulative Preferred Stock
without mandatory redemption requirements ($100 stated value; 10,000,000 shares authorized; issued and outstanding 115,293 shares)	11,529		11,529
Equity:
PNM common stockholder’s equity:
Common stock (no par value; 40,000,000 shares authorized; issued and outstanding 39,117,799 shares)	1,602,918		1,547,918
Accumulated other comprehensive income (loss), net of income taxes	(75,708)		(66,505)
Retained earnings	610,088		469,404
Total PNM common stockholder’s equity	2,137,298		1,950,817
Non-controlling interest in Valencia	46,900		49,958
Total equity	2,184,198		2,000,775
	$	7,407,279	$	6,813,065

The accompanying notes, as they relate to PNM, are an integral part of these consolidated financial statements.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY


	Attributable to PNM
	Common Stock		AOCI		Retained Earnings		Total PNM Common Stockholder’s Equity		Non- controlling Interest in Valencia		Total Equity
	(In thousands)


Balance at December 31, 2021	$	1,547,918	$	(71,936)	$	483,877	$	1,959,859	$	55,405	$	2,015,264
Net earnings	—		—		103,898		103,898		15,122		119,020
Total other comprehensive income (loss)	—		(2,399)		—		(2,399)		—		(2,399)
Dividends declared on preferred stock	—		—		(528)		(528)		—		(528)

Dividends declared on common stock	—		—		(153,500)		(153,500)		—		(153,500)
Valencia’s transactions with its owner	—		—		—		—		(17,533)		(17,533)

Balance at December 31, 2022	1,547,918		(74,335)		433,747		1,907,330		52,994		1,960,324



Net earnings	—		—		36,185		36,185		18,533		54,718
Total other comprehensive income	—		7,830		—		7,830		—		7,830
Dividends declared on preferred stock	—		—		(528)		(528)		—		(528)


Valencia’s transactions with its owner	—		—		—		—		(21,569)		(21,569)
Balance at December 31, 2023	1,547,918		(66,505)		469,404		1,950,817		49,958		2,000,775



Net earnings	—		—		192,212		192,212		16,040		208,252
Total other comprehensive income (loss)	—		(9,203)		—		(9,203)		—		(9,203)
Dividends declared on preferred stock	—		—		(528)		(528)		—		(528)
Equity contribution from parent	55,000		—		—		55,000		—		55,000
Dividends declared on common stock	—		—		(51,000)		(51,000)		—		(51,000)
Valencia’s transactions with its owner	—		—		—		—		(19,098)		(19,098)
Balance at December 31, 2024	$	1,602,918	$	(75,708)	$	610,088	$	2,137,298	$	46,900	$	2,184,198

The accompanying notes, as they relate to PNM, are an integral part of these consolidated financial statements.

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED STATEMENTS OF EARNINGS


	Year Ended December 31,
	2024		2023		2022
	(In thousands)





Electric Operating Revenues	$	592,111	$	535,250	$	482,730
Operating Expenses:
Cost of energy	149,066		138,647		123,928
Administrative and general	54,711		53,963		49,592
Regulatory disallowances	—		1,173		—
Depreciation and amortization	125,915		113,142		98,316
Transmission and distribution costs	37,078		36,996		36,406
Taxes other than income taxes	44,441		41,311		38,521
Total operating expenses	411,211		385,232		346,763
Operating income	180,900		150,018		135,967
Other Income and Deductions:

Other income	12,305		10,127		10,641
Other (deductions)	(3,580)		(1,759)		(1,988)
Net other income	8,725		8,368		8,653
Interest Charges	58,983		46,152		37,192
Earnings before Income Taxes	130,642		112,234		107,428
Income Taxes	27,114		17,297		15,161
Net Earnings	$	103,528	$	94,937	$	92,267

The accompanying notes, as they relate to TNMP, are an integral part of these consolidated financial statements.

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	103,528	$	94,937	$	92,267
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	126,868		113,854		99,165
Deferred income tax (benefit)	26,363		2,888		(4,556)
Regulatory disallowances	—		1,173		—

Allowance for equity funds used during construction and other, net	(5,222)		(5,145)		(4,477)

Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(2,053)		1,916		(12,356)
Materials and supplies	(7,889)		(5,620)		(3,723)
Other current assets	11,063		3,650		(264)
Other assets	(33,601)		3,109		3,834
Accounts payable	(832)		171		195
Accrued interest and taxes	(818)		2,886		14,667
Other current liabilities	(5,355)		(156)		11,952
Other liabilities	1,564		949		(1,757)
Net cash flows from operating activities	213,616		214,612		194,947
Cash Flows From Investing Activities:
Utility plant additions	(541,604)		(464,436)		(449,534)
Net cash flows used in investing activities	(541,604)		(464,436)		(449,534)

The accompanying notes, as they relate to TNMP, are an integral part of these consolidated financial statements.

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS


	Year Ended December 31,
	2024		2023		2022
	(In thousands)

Cash Flow From Financing Activities:
Revolving credit facilities borrowings	$	637,000	$	407,600	$	480,500
Revolving credit facilities repayments	(540,500)		(389,200)		(444,200)

Long-term borrowings	285,000		185,000		160,000
Repayment of long-term debt	(80,000)		—		—

Transmission interconnection arrangements	11,250		11,000		6,400
Refunds paid under transmission interconnection and security deposit arrangements	(4,850)		(3,500)		(14,150)
Equity contribution from parent	24,000		40,900		68,000

Debt issuance costs and other, net	(3,679)		(1,976)		(1,963)
Net cash flows from financing activities	328,221		249,824		254,587

Change in Cash and Cash Equivalents	233		—		—
Cash and Cash Equivalents at Beginning of Year	—		—		—
Cash and Cash Equivalents at End of Year	$	233	$	—	$	—

Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	50,956	$	41,847	$	33,974
Income taxes paid, net	$	11,021	$	16,904	$	9,245

Supplemental schedule of noncash investing activities:
(Increase) decrease in accrued plant additions	$	(16,328)	$	(17,297)	$	(9,131)

The accompanying notes, as they relate to TNMP, are an integral part of these consolidated financial statements.

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED BALANCE SHEETS


	December 31,
	2024		2023
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	233	$	—
Accounts receivable	34,419		31,412
Unbilled revenues	16,193		17,147
Other receivables	15,144		26,983

Materials and supplies	24,351		16,462
Regulatory assets	5,268		50

Other current assets	4,908		2,705
Total current assets	100,516		94,759
Other Property and Investments:
Other investments	75		102
Non-utility property, including financing leases	13,137		14,746
Total other property and investments	13,212		14,848
Utility Plant:
Plant in service and plant held for future use	3,635,550		3,210,870
Less accumulated depreciation and amortization	616,741		582,140
	3,018,809		2,628,730
Construction work in progress	165,527		91,274
Net utility plant	3,184,336		2,720,004
Deferred Charges and Other Assets:
Regulatory assets	104,693		75,654
Goodwill	226,665		226,665
Operating lease right-of-use assets, net of accumulated amortization	923		1,814
Other deferred charges	18,780		11,287
Total deferred charges and other assets	351,061		315,420
	$	3,649,125	$	3,145,031

The accompanying notes, as they relate to TNMP, are an integral part of these consolidated financial statements.

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED BALANCE SHEETS


	December 31,
	2024		2023
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:
Short-term debt	$	151,600	$	55,100

Current installments of long-term debt	—		79,947
Accounts payable	67,116		51,620
Affiliate payables	7,339		6,932
Accrued interest and taxes	56,740		57,558
Regulatory liabilities	602		5,159
Operating lease liabilities	713		895
Other current liabilities	6,964		12,084
Total current liabilities	291,074		269,295
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	1,464,079		1,180,933
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	208,107		178,748
Regulatory liabilities	230,037		206,296
Asset retirement obligations	955		898
Accrued pension liability and postretirement benefit cost	998		1,480
Operating lease liabilities	167		809
Other deferred credits	88,519		68,911
Total deferred credits and other liabilities	528,783		457,142
Total liabilities	2,283,936		1,907,370
Commitments and Contingencies (See Note 16)
Common Stockholder’s Equity:
Common stock ($10 par value; 12,000,000 shares authorized; issued and outstanding 6,358 shares)	64		64
Paid-in-capital	870,066		846,066

Retained earnings	495,059		391,531
Total common stockholder’s equity	1,365,189		1,237,661
	$	3,649,125	$	3,145,031

The accompanying notes, as they relate to TNMP, are an integral part of these consolidated financial statements.

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF TXNM ENERGY, INC.

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCKHOLDER’S EQUITY


	Common Stock		Paid-in Capital		Retained Earnings		Total Common Stockholder’s Equity
	(In thousands)
Balance at December 31, 2021	$	64	$	737,166	$	204,327	$	941,557

Net earnings	—		—		92,267		92,267

Equity contribution from parent	—		68,000		—		68,000

Balance at December 31, 2022	64		805,166		296,594		1,101,824
Net earnings	—		—		94,937		94,937

Equity contributions from parent	—		40,900		—		40,900

Balance at December 31, 2023	64		846,066		391,531		1,237,661
Net earnings	—		—		103,528		103,528

Equity contributions from parent	—		24,000		—		24,000

Balance at December 31, 2024	$	64	$	870,066	$	495,059	$	1,365,189

The accompanying notes, as they relate to TNMP, are an integral part of these consolidated financial statements.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

(1)Summary of the Business and Significant Accounting Policies

Nature of Business

TXNM is an investor-owned holding company with two regulated utilities providing electricity and electric services in New Mexico and Texas. TXNM’s primary subsidiaries are PNM and TNMP. PNM is a public utility with regulated operations primarily engaged in the generation, transmission, and distribution of electricity. In 2023, ETBC I, a special purpose entity that is wholly-owned by PNM, was formed for the limited purpose of purchasing, owning, and administering energy transition property, issuing Securitized Bonds, and performing related activities. See Note 7. TNMP is a wholly-owned subsidiary of TNP, which is a holding company that is wholly-owned by TXNM. TNMP provides regulated transmission and distribution services in Texas. TXNM’s common stock trades on the New York Stock Exchange under the symbol TXNM.

Financial Statement Preparation and Presentation

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could ultimately differ from those estimated.

On August 2, 2024, PNM Resources, Inc. (“PNMR”) amended its Articles of Incorporation to change its name to TXNM Energy, Inc. (“TXNM”) and increased the number of authorized shares of the Company’s common stock from 120,000,000 to 200,000,000. The Notes to Consolidated Financial Statements include disclosures for TXNM, PNM, and TNMP. This report uses the term “Company” when discussing matters of common applicability to TXNM, PNM, and TNMP. Discussions regarding only TXNM, PNM, or TNMP are so indicated. Certain amounts in the 2023 and 2022 Consolidated Financial Statements and Notes thereto have been reclassified to conform to the 2024 financial statement presentation.

GAAP defines subsequent events as events or transactions that occur after the balance sheet date but before financial statements are issued or are available to be issued. Based on their nature, magnitude, and timing, certain subsequent events may be required to be reflected at the balance sheet date and/or required to be disclosed in the financial statements. The Company has evaluated subsequent events accordingly.

Principles of Consolidation

The Consolidated Financial Statements of each of TXNM, PNM, and TNMP include their accounts and those of subsidiaries in which that entity owns a majority voting interest. PNM also consolidates Valencia and ETBC I (Note 10). PNM owns undivided interests in jointly-owned power plants and records its pro-rata share of the assets, liabilities, and expenses for those plants. The agreements for the jointly-owned plants provide that if an owner were to default on its payment obligations, the non-defaulting owners would be responsible for their proportionate share of the obligations of the defaulting owner. In exchange, the non-defaulting owners would be entitled to their proportionate share of the generating capacity of the defaulting owner. There have been no such payment defaults under any of the agreements for the jointly-owned plants.

PNMR Services Company expenses, which represent costs that are primarily driven by corporate level activities, are charged to the business segments. These services are billed at cost and are reflected as general and administrative expenses in the business segments. Other significant intercompany transactions between TXNM, PNM, and TNMP include intercompany loans, interest and income tax sharing payments, as well as equity transactions, and interconnection billings. All intercompany transactions and balances have been eliminated. See Note 20.

Accounting for the Effects of Certain Types of Regulation

The Company maintains its accounting records in accordance with the uniform system of accounts prescribed by FERC and adopted by the NMPRC and PUCT.

Certain of the Company’s operations are regulated by the NMPRC, PUCT, and FERC and the provisions of GAAP for rate-regulated enterprises are applied to the regulated operations. Regulators may assign costs to accounting periods that differ from accounting methods applied by non-regulated utilities. When it is probable that regulators will permit recovery of costs through future rates, costs are deferred as regulatory assets that otherwise would be expensed. Likewise, regulatory liabilities are recognized when it is probable that regulators will require refunds through future rates or when revenue is collected for

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

expenditures that have not yet been incurred. GAAP also provides for the recognition of revenue and regulatory assets and liabilities associated with “alternative revenue programs” authorized by regulators. Such programs allow the utility to adjust future rates in response to past activities or completed events, if certain criteria are met. Regulatory assets and liabilities are amortized into earnings over the authorized recovery period. Accordingly, the Company has deferred certain costs and recorded certain liabilities pursuant to the rate actions of the NMPRC, PUCT, and FERC. Information on regulatory assets and regulatory liabilities is contained in Note 13.

In some circumstances, regulators allow a requested increase in rates to be implemented, subject to refund, before the regulatory process has been completed and a decision rendered by the regulator. When this occurs, the Company assesses the possible outcomes of the rate proceeding. The Company records a provision for refund to the extent the amounts being collected, subject to refund, exceed the amount the Company determines is probable of ultimately being allowed by the regulator.

Cash and Restricted Cash

Investments in highly liquid investments with original maturities of three months or less at the date of purchase are considered cash and cash equivalents. Cash deposits received and held for a period of time that are restricted to a specific purpose, under the terms of their effective agreements, are considered restricted cash. PNM and TXNM have restricted cash balances related to the ETBC I Securitized Bonds. Restricted cash amounts are included in Other current assets and Other deferred charges on the Consolidated Balance Sheets as of December 31, 2024 and 2023. See Note 10. At December 31, 2024 and 2023 there was no restricted cash for TNMP. At December 31, 2022 there was no restricted cash for TXNM, PNM, and TNMP.

Utility Plant

Utility plant is stated at original cost and includes capitalized payroll-related costs such as taxes, pension, other fringe benefits, administrative costs, and AFUDC, where authorized by rate regulation, or capitalized interest.

Repairs, including major maintenance activities, and minor replacements of property are expensed when incurred, except as required by regulators for ratemaking purposes. Major replacements are charged to utility plant. Gains, losses, and costs to remove resulting from retirements or other dispositions of regulated property in the normal course of business are credited or charged to accumulated depreciation.

PNM and TNMP may receive reimbursements, referred to as CIAC, from customers to pay for all or part of certain construction projects to the extent the project does not benefit regulated customers in general. PNM and TNMP account for these reimbursements as offsets to utility plant additions based on the requirements of the NMPRC, FERC, and PUCT. Due to the PUCT’s regulatory treatment of CIAC reimbursements, TNMP also receives a financing component that is recognized as Other income on the Consolidated Statements of Earnings. Under the NMPRC regulatory treatment, PNM typically does not receive a financing component.

Depreciation and Amortization

PNM’s provision for depreciation and amortization of utility plant, other than nuclear fuel, is based upon straight-line rates approved by the NMPRC and FERC. Amortization of nuclear fuel is based on units-of-production. TNMP’s provision for depreciation and amortization of utility plant is based upon straight-line rates approved by the PUCT. Depreciation and amortization of non-utility property, including right-of-use assets for finance leases as discussed in Note 8, is computed based on the straight-line method. The provision for depreciation of certain equipment is allocated between operating expenses and construction projects based on the use of the equipment.

Average straight-line rates used were as follows:


	Year ended December 31,
	2024		2023		2022
PNM
Electric plant	2.87	%	2.67	%	2.55	%
Common, intangible, and general plant	14.06		7.64		7.83
TNMP	3.74		3.77		3.72

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Depreciation expense on electric, common, intangible, and general plant is as follows:


	Year ended December 31,
	2024		2023		2022
	(In thousands)
PNM	$	188,035	$	158,956	$	163,162
TNMP	124,976		110,675		96,131

Allowance for Funds Used During Construction

As provided by the FERC uniform systems of accounts, AFUDC is charged to regulated utility plant for construction projects. This allowance is designed to enable a utility to capitalize financing costs during periods of construction of property subject to rate regulation. It represents the cost of borrowed funds (allowance for borrowed funds used during construction or “debt AFUDC”) and a return on other funds (allowance for equity funds used during construction or “equity AFUDC”). The debt AFUDC is recorded in interest charges and the equity AFUDC is recorded in other income on the Consolidated Statements of Earnings.

For the years ended December 31, 2024, 2023, and 2022, PNM recorded $12.9 million, $9.5 million, and $3.7 million of debt AFUDC at annual rates of 3.19%, 2.99%, and 1.70% and $13.0 million, $9.8 million, and $9.3 million of equity AFUDC at annual rates of 3.30%, 3.24%, and 4.26%. For the years ended December 31, 2024, 2023, and 2022, TNMP recorded $8.0 million, $5.7 million, and $3.4 million of debt AFUDC at rates of 4.14%, 3.49%, and 2.25% and $4.8 million, $5.1 million, and $4.5 million of equity AFUDC at rates of 2.48%, 3.17%, and 2.99%.

Materials, Supplies, and Fuel Stock

Materials and supplies relate to transmission, distribution, and generating assets. Materials and supplies are charged to inventory when purchased and are expensed or capitalized as appropriate when issued. Materials and supplies are valued using an average costing method. Inventories consisted of the following at December 31:


	TXNM				PNM				TNMP
	2024		2023		2024		2023		2024		2023
	(In thousands)
Fuel Oil	$	1,095	$	896	$	1,095	$	896	$	—	$	—
Materials and supplies	165,766		97,138		141,415		80,676		24,351		16,462
	$	166,861	$	98,034	$	142,510	$	81,572	$	24,351	$	16,462

Investments

PNM holds investment securities in the NDT for the purpose of funding its share of the decommissioning costs of PVNGS, a trust for PNM’s share of decommissioning costs at SJGS, and trusts for PNM’s share of final reclamation costs related to the coal mines that served SJGS and continue to serve Four Corners (Note 16). Investments (both equity and available-for-sale debt securities) are measured at fair value on a quarterly basis with changes in fair value for equity securities recognized in earnings for that period. Since third party investment managers have sole discretion over the purchase and sale of the securities (under general guidelines and targets provided by management), PNM records an impairment, as a realized loss, for any available-for-sale debt security that has a fair value which is less than cost at the end of each quarter. For the years ended December 31, 2024, 2023 and 2022, PNM recorded impairment losses on the available-for-sale debt securities of $17.8 million, $(19.1) million and $25.8 million. No gains or losses are deferred as regulatory assets or liabilities. See Notes 3 and 9. All investments are held in PNM’s name and are in the custody of major financial institutions. The specific identification method is used to determine the cost of securities disposed of, with realized gains and losses reflected in other income and deductions.

As discussed above, PNM immediately records an impairment loss for any available-for-sale debt security that has a fair value that is less than its carrying value. As a result, the Company has no available-for-sale debt securities for which carrying value exceeds fair value and there are no impairments considered to be “other than temporary” that are included in AOCI and not recognized in earnings. All gains and losses resulting from sales and changes in the fair value of equity securities are recognized immediately in earnings.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Equity Method Investment

TXNM accounted for its investment in NMRD using the equity method of accounting because TXNM’s ownership interest resulted in significant influence, but not control, over NMRD and its operations. TXNM recorded as income its percentage share of earnings or loss of NMRD and carried its investment at cost, adjusted for its share of undistributed earnings or losses, until its investment was sold on February 27, 2024. See Note 21.

Goodwill

The Company does not amortize goodwill. Goodwill is evaluated for impairment annually, or more frequently if events and circumstances indicate that the goodwill might be impaired. See Note 19.

Asset Impairment

Tangible long-lived assets and right-of-use assets associated with leases are evaluated in relation to the estimated future undiscounted cash flows to assess recoverability when events and circumstances indicate that the assets might be impaired.

Revenue Recognition

See Note 4 for a discussion of electric operating revenues.

Accounts Receivable and Allowance for Credit Losses

See Note 4 for a discussion of accounts receivable and the allowance for credit losses.

Amortization of Debt Acquisition Costs

Discount, premium, and expense related to the issuance of long-term debt are amortized over the lives of the respective issues. Gains and losses incurred upon the early retirement of long-term debt are recognized in other income or other deductions, except for amounts recoverable through NMPRC, FERC, or PUCT regulation, which are recorded as regulatory assets or liabilities and amortized over the lives of the respective issues. Unamortized premium, discount, and expense related to long-term debt are reflected as part of the related liability on the Consolidated Balance Sheets.

Derivatives

The Company records derivative instruments, including energy contracts, on the balance sheet as either an asset or liability measured at their fair value. Changes in the derivatives’ fair value are recognized in earnings unless specific hedge accounting criteria are met. PNM also records certain commodity derivative transactions recoverable through NMPRC regulation as regulatory assets or liabilities. See Note 9.

The Company treats all forward commodity purchases and sales contracts subject to unplanned netting or “book-out” by the transmission provider as derivative instruments subject to mark-to-market accounting. GAAP provides guidance on whether realized gains and losses on derivative contracts not held for trading purposes should be reported on a net or gross basis and concludes such classification is a matter of judgment that depends on the relevant facts and circumstances. See Note 4.

Decommissioning and Reclamation Costs

PNM is only required to recognize and measure decommissioning liabilities for tangible long-lived assets for which a legal obligation exists. Nuclear decommissioning costs and related accruals are based on periodic site-specific estimates of the costs for removing all radioactive and other structures at PVNGS and are dependent upon numerous assumptions, including estimates of future decommissioning costs at current price levels, inflation rates, and discount rates. PNM’s accruals for PVNGS Units 1, 2, and 3, including portions previously held under leases, have been made based on such estimates, the guidelines of the NRC, and the PVNGS license periods. PNM records its share of the SJGS decommissioning obligation as an ARO on its Consolidated Balance Sheets. Studies on the decommissioning costs of SJGS are performed periodically and revisions to the ARO liability are recorded. See Note 16.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

In connection with both the SJGS and Four Corners coal supply agreements, the owners are required to reimburse the mining companies for the cost of contemporaneous reclamation, as well as the costs for final reclamation of the coal mines. The reclamation costs are based on periodic site-specific studies that estimate the costs to be incurred in the future and are dependent upon numerous assumptions, including estimates of future reclamation costs at current price levels, inflation rates, and discount rates. PNM considers the contemporaneous reclamation costs part of the cost of its delivered coal costs. See Note 16 for a discussion of reclamation costs.

Environmental Costs

The normal operations of the Company involve activities and substances that expose the Company to potential liabilities under laws and regulations protecting the environment. Liabilities under these laws and regulations can be material and may be imposed without regard to fault, or may be imposed for past acts, even though the past acts may have been lawful at the time they occurred.

The Company records its environmental liabilities when site assessments or remedial actions are probable, and a range of reasonably likely cleanup costs can be estimated. The Company reviews its sites and measures the liability by assessing a range of reasonably likely costs for each identified site using currently available information and the probable level of involvement and financial condition of other potentially responsible parties. These estimates are based on assumptions regarding the costs for site investigations, remediation, operations and maintenance, monitoring, and site closure. The ultimate cost to clean up the Company’s identified sites varies from its recorded liability due to numerous uncertainties inherent in the estimation process. See Note 16.

Pension and Other Postretirement Benefits

See Note 11 for a discussion of pension and postretirement benefits expense, including a discussion of the actuarial assumptions.

Stock-Based Compensation

See Note 12 for a discussion of stock-based compensation expense.

Income Taxes

Income taxes are recognized using the asset and liability method of accounting for income taxes. Deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying value of existing assets and liabilities and their respective tax basis. All deferred taxes are reflected as non-current on the Consolidated Balance Sheets. Current NMPRC, FERC, and PUCT approved rates include the tax effects of the majority of these differences. Rate-regulated enterprises are required to record deferred income taxes for temporary differences accorded flow-through treatment at the direction of a regulatory commission. The resulting deferred tax assets and liabilities are recorded based on the expected cash flow to be reflected in future rates. Because the NMPRC, FERC, and the PUCT have consistently permitted the recovery of tax effects previously flowed-through earnings, the Company has established regulatory assets and liabilities offsetting such deferred tax assets and liabilities. The Company recognizes only the impact of tax positions that, based on their merits, are more likely than not to be sustained upon an IRS audit. The Company defers investment tax credits and amortizes them over the estimated useful lives of the assets. See Note 18 for additional information, including a discussion of the impacts of the Tax Act.

The Company makes an estimate of its anticipated effective tax rate for the year as of the end of each quarterly period within its fiscal year. In interim periods, income tax expense is calculated by applying the anticipated annual effective tax rate to year-to-date earnings before taxes. Certain unusual or infrequently occurring items, as well as adjustments due to enactment of new tax laws, have been excluded from the estimated annual effective tax rate calculation.

Lease Commitments

See Note 8 for a discussion of lease commitments.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

New Accounting Pronouncements

Information concerning recently issued accounting pronouncements that have not yet been adopted by the Company is presented below. The Company does not expect difficulty in adopting these standards by their required effective dates.

Accounting Standards Update 2023-09 - Income Taxes (Topic 740): Improvements to Income Tax Disclosures

In December 2023, the FASB issued ASU 2023-09 enhancing the transparency and decision usefulness of income tax disclosures. Disclosure requirements of this update include (on an annual basis) the disclosure of specific categories in the rate reconciliation and the inclusion of additional information for reconciling items that meet a quantitative threshold (if the effect of the reconciling item is equal to or greater than 5 percent of the amount computed by multiplying pre-tax income by the applicable statutory rate). The amendment also requires the disclosure (on an annual basis) of information about income taxes paid (net of refunds) including, the disaggregation by federal, state, and foreign taxes as well as by individual jurisdiction. Additional requirements include the disclosure of income (loss) from continuing operations before income tax expense (benefit) disaggregated between foreign and domestic as well as income tax expense (benefit) from continuing operations disaggregated by federal, state, and foreign. ASU 2023-09 is effective for the Company beginning January 1, 2025 with early adoption being permitted. ASU 2023-09 is to be applied on a prospective basis with retrospective application permitted.

Accounting Standards Update 2024-03 - Income Statement (Subtopic 220-40): Reporting Comprehensive Income - Expense Disaggregation Disclosures

In November 2024, the FASB issued ASU 2024-03 that will require disclosure, in the notes to the financial statements, of specified information about certain costs and expenses at each interim and annual period. Disclosures should include amounts for purchases of inventory, employee compensation, depreciation and, intangible asset amortization; certain amounts that are already required to be disclosed under GAAP in the same disclosure as other disaggregation requirements; qualitative descriptions of the amounts remaining in relevant expense categories that are not disaggregated; the total amount of selling expenses including the entity’s definition of selling expenses. In January 2025, ASU 2025-01 was issued to clarify that the amendments of ASU 2024-03 are effective for public business entities for annual reporting periods beginning after December 15, 2026 and interim reporting periods beginning after December 15, 2027.

(2)Segment Information

TXNM has three reportable segments including PNM, TNMP, and Corporate and other. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. The measure of profitability used by the CODM is Segment earnings (loss) attributable to TXNM, as presented below. The CODM uses this measure of profitability to allocate resources for each segment predominantly in the annual budget and forecasting process. The CODM considers budget to actual variances on a regular basis when making decisions about allocating capital and operational expense funding to the segments. TXNM’s CODM is its President and COO who is also the CEO of the PNM and TNMP segments.

PNM

PNM includes the retail electric utility operations of PNM that are subject to traditional rate regulation by the NMPRC. PNM provides integrated electricity services that include the generation, transmission, and distribution of electricity for retail electric customers in New Mexico. PNM also includes the generation and sale of electricity into the wholesale market, which includes the asset optimization of PNM’s jurisdictional capacity as well as providing transmission services to third parties. FERC has jurisdiction over wholesale power and transmission rates. PNM includes the results of ETBC I upon its formation in 2023.

TNMP

TNMP is an electric utility providing services in Texas under the TECA. TNMP’s operations are subject to traditional rate regulation by the PUCT. TNMP provides transmission and distribution services at regulated rates to various REPs that, in turn, provide retail electric service to consumers within TNMP’s service area. TNMP also provides transmission services at regulated rates to other utilities that interconnect with TNMP’s facilities.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Corporate and Other

The Corporate and Other segment includes TXNM holding company activities, primarily related to corporate level debt and PNMR Services Company. The activities of PNMR Development and the equity method investment in NMRD are also included in Corporate and Other until the close of the sale of NMRD on February 27, 2024 (Note 21). Eliminations of intercompany transactions are reflected in the Corporate and Other segment.

The following tables present summarized financial information for TXNM by segment. PNM and TNMP each operate in only one segment. Therefore, tabular segment information is not presented for PNM and TNMP.


2024	PNM		TNMP		Corporate and Other		TXNM Consolidated
	(In thousands)
Electric operating revenues	$	1,379,088	$	592,111	$	—	$	1,971,199
Cost of energy
Fuel burn	130,380		—		—		130,380
Purchases for resale	286,399		—		—		286,399
Transmission by others	18,139		149,066		—		167,205
Significant segment expenses
Administrative and general - direct	63,105		(1,452)		151,089		212,742
Administrative and general - corporate allocation	132,209		53,166		(185,375)		—
Customer related expenses	31,246		2,997		131		34,374
Energy production costs	93,748		—		—		93,748
Regulatory disallowances	8,980		—		—		8,980
Depreciation and amortization	221,780		125,915		37,230		384,925
Transmission and distribution costs	61,302		37,078		—		98,380
Taxes other than income taxes	49,807		44,441		6,332		100,580
Total operating expenses	1,097,095		411,211		9,407		1,517,713

Net other income and (deductions)	61,494		8,725		(15,399)		54,820
Interest charges	(106,018)		(58,983)		(63,065)		(228,066)
Income taxes (benefit)	29,217		27,114		(34,813)		21,518
Valencia non-controlling interest	(16,040)		—		—		(16,040)
Subsidiary preferred stock dividends	(528)		—		—		(528)

Segment earnings (loss) attributable to TXNM	$	191,684	$	103,528	$	(53,058)	$	242,154


At December 31, 2024:
Total Assets	$	7,407,279	$	3,649,125	$	155,329	$	11,211,733
Goodwill	$	51,632	$	226,665	$	—	$	278,297

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022


2023	PNM		TNMP		Corporate and Other		TXNM Consolidated
	(In thousands)
Electric operating revenues	$	1,403,948	$	535,250	$	—	$	1,939,198
Cost of energy
Fuel burn	138,538		—		—		138,538
Purchases for resale	499,921		—		—		499,921
Transmission by others	25,155		138,647		—		163,802
Significant segment expenses
Administrative and general - direct	52,554		2,710		139,010		194,274
Administrative and general - corporate allocation	124,321		47,470		(171,791)		—
Customer related expenses	29,775		3,783		68		33,626
Energy production costs	91,610		—		—		91,610
Regulatory disallowances	70,750		1,173		—		71,923
Depreciation and amortization	177,633		113,142		28,728		319,503
Transmission and distribution costs	61,725		36,996		—		98,721
Taxes other than income taxes	48,790		41,311		5,839		95,940
Total operating expenses	1,320,772		385,232		1,854		1,707,858

Net other income and (deductions)	41,358		8,368		(182)		49,544
Interest charges	(86,574)		(46,152)		(57,629)		(190,355)
Income taxes (benefit)	(16,758)		17,297		(16,889)		(16,350)
Valencia non-controlling interest	(18,533)		—		—		(18,533)
Subsidiary preferred stock dividends	(528)		—		—		(528)

Segment earnings (loss) attributable to TXNM	$	35,657	$	94,937	$	(42,776)	$	87,818


At December 31, 2023:
Total Assets	$	6,813,065	$	3,145,031	$	294,509	$	10,252,605
Goodwill	$	51,632	$	226,665	$	—	$	278,297

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022


2022	PNM		TNMP		Corporate and Other		TXNM Consolidated
	(In thousands)
Electric operating revenues	$	1,766,825	$	482,730	$	—	$	2,249,555
Cost of energy
Fuel burn	299,411		—		—		299,411
Purchases for resale	541,828		—		—		541,828
Trading mark-to-market	(456)		—		—		(456)
Transmission by others	23,230		123,928		—		147,158
Significant segment expenses
Administrative and general - direct	62,505		3,607		130,336		196,448
Administrative and general - corporate allocation	115,416		42,293		(157,709)		—
Customer related expenses	26,925		3,692		84		30,701
Energy production costs	147,347		—		—		147,347
Regulatory disallowances	832		—		—		832
Depreciation and amortization	180,812		98,316		25,725		304,853
Transmission and distribution costs	58,278		36,406		—		94,684
Taxes other than income taxes	49,210		38,521		5,258		92,989
Total operating expenses	1,505,338		346,763		3,694		1,855,795

Net other income and (deductions)	(62,196)		8,653		(999)		(54,542)
Interest charges	(61,073)		(37,192)		(29,643)		(127,908)
Income taxes (benefit)	19,198		15,161		(8,229)		26,130
Valencia non-controlling interest	(15,122)		—		—		(15,122)
Subsidiary preferred stock dividends	(528)		—		—		(528)

Segment earnings (loss) attributable to TXNM	$	103,370	$	92,267	$	(26,107)	$	169,530


At December 31, 2022:
Total Assets	$	6,272,166	$	2,746,601	$	238,610	$	9,257,377
Goodwill	$	51,632	$	226,665	$	—	$	278,297

Significant Segment Expenses

Reflected above are certain additional categories of operating expenses that are regularly provided to the CODM. Cost of energy consists primarily of fuel and purchase power costs for PNM and costs charged by third-party transmission providers for TNMP. Administrative and general - direct expenses are those that are incurred directly by the segment while corporate allocation are those costs that are incurred by the corporate and other segment and allocated to the utilities based on the nature of the cost incurred. Corporate allocation is eliminated in the corporate and other segment. Customer related expenses include meter reading, customer service, and bad debt expenses.

Major Customers

PNM’s participation in EIM, operated by CAISO, accounted for approximately 4%, 15%, and 24% of electric operating revenues during the years ended December 31, 2024, 2023, and 2022. These revenues are passed on to customers under PNM’s FPPAC with no impact to net earnings. Two REPs during the years ended December 31, 2024, 2023, and 2022 accounted for more than 10% of the electric operating revenues of TNMP as follows:


	Year Ended December 31,
	2024		2023		2022
REP A	26	%	25	%	27	%
REP B	20		19		20

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

(3)Accumulated Other Comprehensive Income (Loss)

AOCI reports a measure for accumulated changes in equity that result from transactions and other economic events other than transactions with shareholders. Information regarding AOCI is as follows:


	Accumulated Other Comprehensive Income (Loss)
	PNM						TXNM
	Unrealized Gains on Available-for-Sale Securities		Pension Liability Adjustment		Total		Fair Value Adjustment for Cash Flow Hedges		Total
	(In thousands)



Balance at December 31, 2021	$	11,715	$	(83,651)	$	(71,936)	$	—	$	(71,936)
Amounts reclassified from AOCI (pre-tax)	(3,827)		7,104		3,277		(1,176)		2,101
Income tax impact of amounts reclassified	972		(1,804)		(832)		299		(533)
Other OCI changes (pre-tax)	(1,928)		(4,565)		(6,493)		12,285		5,792
Income tax impact of other OCI changes	490		1,159		1,649		(3,121)		(1,472)
Net after-tax change	(4,293)		1,894		(2,399)		8,287		5,888

Balance at December 31, 2022	7,422		(81,757)		(74,335)		8,287		(66,048)





Amounts reclassified from AOCI (pre-tax)	(7,199)		4,776		(2,423)		9,287		6,864
Income tax impact of amounts reclassified	1,828		(1,212)		616		(2,359)		(1,743)
Other OCI changes (pre-tax)	11,529		1,389		12,918		(15,483)		(2,565)
Income tax impact of other OCI changes	(2,928)		(353)		(3,281)		3,933		652
Net after-tax change	3,230		4,600		7,830		(4,622)		3,208

Balance at December 31, 2023	10,652		(77,157)		(66,505)		3,665		(62,840)







Amounts reclassified from AOCI (pre-tax)	(13,108)		4,866		(8,242)		10,348		2,106
Income tax impact of amounts reclassified	3,330		(1,236)		2,094		(2,629)		(535)
Other OCI changes (pre-tax)	(885)		(3,210)		(4,095)		(15,260)		(19,355)
Income tax impact of other OCI changes	225		815		1,040		3,876		4,916
Net after-tax change	(10,438)		1,235		(9,203)		(3,665)		(12,868)

Balance at December 31, 2024	$	214	$	(75,922)	$	(75,708)	$	—	$	(75,708)

The Consolidated Statements of Earnings include pre-tax amounts reclassified from AOCI related to Unrealized Gains on Available-for-Sale Debt Securities in gains (losses) on investment securities, related to Pension Liability Adjustment in other (deductions), and related to Fair Value Adjustment for Cash Flow Hedges in interest charges. The income tax impacts of all amounts reclassified from AOCI are included in income taxes in the Consolidated Statements of Earnings.

(4) Electric Operating Revenues

Accounts Receivable and Allowance for Credit Losses

Accounts receivable consists primarily of trade receivables from customers. In the normal course of business, credit is extended to customers on a short-term basis. The Company estimates the allowance for credit losses on trade receivables based on historical experience and estimated default rates. Accounts receivable balances are reviewed monthly, adjustments to the allowance for credit losses are made as necessary and amounts that are deemed uncollectible are written off. In addition to the allowance for credit losses on trade receivables, the Company has evaluated other receivables for potential credit related losses. These balances include potential exposures for other non-retail utility services. In the years ended December 31, 2024 and 2023, there were no estimated credit losses related to these transactions.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Revenue Recognition

Retail electric operating revenues are recorded in the period of energy delivery, which includes estimated amounts for service rendered but unbilled at the end of each accounting period. The determination of the energy sales billed to individual retail customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each month, amounts of energy delivered to customers since the date of the last meter reading and the corresponding unbilled revenue are estimated. Unbilled electric revenue is estimated based on daily generation volumes, estimated customer usage by class, line losses, historical trends and experience, applicable customer rates or by using AMS data where available. Amounts billed are generally due within the next month. The Company does not incur incremental costs to obtain contracts for its energy services.

PNM’s wholesale electricity sales are recorded as electric operating revenues and wholesale electricity purchases are recorded as costs of energy sold. Derivative contracts that are subject to unplanned netting are recorded net in earnings. A “book-out” is the planned or unplanned netting of off-setting purchase and sale transactions. A book-out is a transmission mechanism to reduce congestion on the transmission system or administrative burden. For accounting purposes, a book-out is the recording of net revenues upon the settlement of a derivative contract.

Unrealized gains and losses on derivative contracts that are not designated for hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power and fuel supply agreements, used to hedge generation assets and purchased power costs. Changes in the fair value of economic hedges are reflected in results of operations, with changes related to economic hedges on sales included in operating revenues and changes related to economic hedges on purchases included in cost of energy sold. See Note 9.

The Company has collaborative arrangements related to its interest in SJGS, Four Corners, PVNGS, and Luna. The Company has determined that during the years ended December 31, 2024, 2023, and 2022 none of the joint owners in its collaborative arrangements were customers under Topic 606. The Company will continue to evaluate transactions between collaborative arrangement participants in future periods under the revenue recognition standard.

PNM and TNMP recognize revenue as they satisfy performance obligations, which typically occurs as the customer or end-user consumes the electric service provided. Electric services are typically for a bundle of services that are distinct and transferred to the end-user in one performance obligation measured by KWh or KW. Electric operating revenues are recorded in the period of energy delivery, including estimated unbilled amounts. The Company has elected to exclude all sales and similar taxes from revenue.

Revenue from contracts with customers is recorded based upon the total authorized tariff or market price at the time electric service is rendered, including amounts billed under arrangements qualifying as an Alternative Revenue Program (“ARP”). ARP arrangements are agreements between PNM or TNMP and its regulator that allow PNM or TNMP to adjust future rates in response to past activities or completed events, if certain criteria are met. ARP revenues are required to be reported separately from contracts with customers. ARP revenues in a given period include the recognition of “originating” ARP revenues (i.e. when the regulator-specific conditions are met) in the period, offset by the reversal of ARP revenues currently approved for recovery by the governing bodies.

Sources of Revenue

Additional information about the nature of revenues is provided below. Additional information about matters affecting PNM’s and TNMP’s regulated revenues is provided in Note 17.

Revenue from Contracts with Customers

PNM

NMPRC Regulated Retail Electric Service – PNM provides electric generation, transmission, and distribution service to its rate-regulated customers in New Mexico. PNM’s retail electric service territory covers a large area of north central New Mexico, including the cities of Albuquerque, Rio Rancho, and Santa Fe, and certain areas of southern New Mexico. Customer rates for retail electric service are set by the NMPRC and revenue is recognized as energy is delivered to the customer. PNM invoices customers on a monthly basis for electric service and generally collects billed amounts within one month.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Transmission Service to Third Parties – PNM owns transmission lines that are interconnected with other utilities in New Mexico, Texas, Arizona, Colorado, and Utah. Transmission customers receive service for the transmission of energy owned by the customer utilizing PNM’s transmission facilities. Customers generally receive transmission services, which are regulated by FERC, from PNM through PNM’s Open Access Transmission Tariff (“OATT”) or a specific contract. Customers are billed based on capacity and energy components on a monthly basis. PNM owns the Western Spirit Line and services under related transmission agreements use an incremental rate, approved by FERC, that is separate from the formula rate mechanism.

Wholesale Energy Sales – PNM engages in activities to optimize its existing jurisdictional assets and long-term power agreements through spot market, hour-ahead, day-ahead, week-ahead, month-ahead, and other sales of excess generation not required to fulfill retail load and contractual commitments. PNM participates in the EIM (a real-time wholesale energy trading market operated by the CAISO) that enables participating electric utilities to buy and sell energy. The NMPRC granted PNM authority to seek recovery of costs associated with joining the EIM, which have been included in the 2024 Rate Change and to pass the benefits of participating in EIM to customers through the FPPAC. PNM’s participation in EIM has significantly increased Electric operating revenues which are passed on to customers under PNM’s FPPAC with no impact to net earnings.

TNMP

PUCT Regulated Retail Electric Service – TNMP provides transmission and distribution services in Texas under the provisions of TECA and the Texas Public Utility Regulatory Act. TNMP is subject to traditional cost-of-service regulation with respect to rates and service under the jurisdiction of the PUCT and certain municipalities. TNMP’s transmission and distribution activities are solely within ERCOT and not subject to traditional rate regulation by FERC. TNMP provides transmission and distribution services at regulated rates to various REPs that, in turn, provide retail electric service to consumers within TNMP’s service territory. Revenue is recognized as energy is delivered to the consumer. TNMP invoices REPs on a monthly basis and is generally paid within a month.

TCOS – TNMP is a transmission service provider that is allowed to recover its TCOS through a network transmission rate that is approved by the PUCT. TCOS customers are other utilities that receive service for the transmission of energy owned by the customer utilizing TNMP’s transmission facilities.

Alternative Revenue Programs

The Company defers certain costs and records certain liabilities pursuant to the rate actions of the NMPRC, PUCT, and FERC. ARP revenues, which are discussed above, include recovery or refund provisions under PNM’s renewable energy rider and true-ups to PNM’s formula transmission rates; transmission cost recovery factor, and the impacts of the PUCT’s January 25, 2018 order regarding the change in the federal corporate income tax rate; the energy efficiency incentive bonus at both PNM and TNMP; and PNM’s TOD rate pilot program. Regulatory assets and liabilities are recognized for the difference between ARP revenues and amounts currently approved for recovery by the governing bodies. Regulatory assets and liabilities are amortized into earnings as amounts are billed. TNMP’s 2018 Rate Case integrated AMS costs into base rates beginning January 1, 2019. These costs are being amortized into earnings as alternative revenues over a period of five years.

Other Electric Operating Revenues

Other electric operating revenues consist primarily of PNM’s economic hedges that meet the definition of a derivative and are therefore not considered revenue from contracts with customers. Derivative revenues include gains and losses representing changes in fair value (Note 9) and settlements from sales of electricity under forward sales contracts.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Disaggregation of Revenues

A disaggregation of revenues from contracts with customers by the type of customer is presented in the table below. The table also reflects ARP revenues and other revenues.


	PNM		TNMP		TXNM Consolidated
Year Ended December 31, 2024	(In thousands)
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	541,581	$	203,227	$	744,808
Commercial	460,311		166,858		627,169
Industrial	123,754		35,300		159,054
Public authority	23,161		7,329		30,490
Economy energy service	25,481		—		25,481
Transmission	141,058		157,049		298,107
Wholesale energy sales	64,903		—		64,903
Miscellaneous	5,776		3,813		9,589
Total revenues from contracts with customers	1,386,025		573,576		1,959,601
Alternative revenue programs	(9,720)		18,535		8,815
Other electric operating revenues	2,783		—		2,783
Total Electric Operating Revenues	$	1,379,088	$	592,111	$	1,971,199


	PNM			TNMP		TXNM Consolidated
Year Ended December 31, 2023	(In thousands)
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	425,448		$	190,953	$	616,401
Commercial	391,964			155,254		547,218
Industrial	90,084			45,508		135,592
Public authority	21,018			6,777		27,795
Economy energy service	34,340			—		34,340
Transmission	159,475			135,831		295,306
Wholesale energy sales	248,801			—		248,801
Miscellaneous	5,676			3,739		9,415
Total revenues from contracts with customers	1,376,806		1	538,062		1,914,868		1
Alternative revenue programs	9,419			(2,812)		6,607
Other electric operating revenues	17,723			—		17,723
Total Electric Operating Revenues	$	1,403,948		$	535,250	$	1,939,198

1 Included in revenue from contracts with customers at PNM and TXNM is a $128.7 million reduction associated with the SJGS abandonment settlement and a $38.4 million reduction associated with PVNGS leased capacity as a result of the NMPRC final order in the 2024 Rate Change.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022


	PNM		TNMP		TXNM Consolidated
Year Ended December 31, 2022	(In thousands)
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	484,699	$	187,951	$	672,650
Commercial	422,163		154,059		576,222
Industrial	85,102		36,919		122,021
Public authority	21,330		6,379		27,709
Economy energy service	45,009		—		45,009
Transmission	149,421		113,782		263,203
Wholesale energy sales	534,196		—		534,196
Miscellaneous	5,390		3,817		9,207
Total revenues from contracts with customers	1,747,310		502,907		2,250,217
Alternative revenue programs	692		(20,177)		(19,485)
Other electric operating revenues	18,823		—		18,823
Total Electric Operating Revenues	$	1,766,825	$	482,730	$	2,249,555

Contract Balances

Performance obligations related to contracts with customers are typically satisfied when the energy is delivered, and the customer or end-user utilizes the energy. Accounts receivable from customers represent amounts billed, including amounts under ARPs. For PNM, accounts receivable reflected on the Consolidated Balance Sheets, net of allowance for credit losses, includes $94.3 million and $93.6 million at December 31, 2024 and 2023 resulting from contracts with customers. All of TNMP’s accounts receivable results from contracts with customers.

Contract assets are an entity’s right to consideration in exchange for goods or services that the entity has transferred to a customer when that right is conditioned on something other than the passage of time (for example, the entity’s future performance). Upon the completion of the Western Spirit Line, PNM entered into a TSA with Pattern Wind under an incremental tariff rate approved by FERC. The terms of the agreement provide for a financing component that benefits the customer. As such, the revenue that PNM recognizes will be in excess of the consideration received at the beginning of the service term resulting in a contract asset. The balance of the contract asset was $32.0 million at December 31, 2024 and $22.1 million at December 31, 2023, and is included in Other deferred charges on the Consolidated Balance Sheets.

Contract liabilities arise when consideration is received in advance from a customer before satisfying the performance obligations. Therefore, revenue is deferred and not recognized until the obligation is satisfied. Under its OATT, PNM accepts upfront consideration for capacity reservations requested by transmission customers, which requires PNM to defer the customer’s transmission capacity rights for a specific period of time. PNM recognizes the revenue of these capacity reservations over the period it defers the customer’s capacity rights. Other utilities pay PNM and TNMP in advance for the joint-use of their utility poles. These revenues are recognized over the period of time specified in the joint-use contract, typically for one calendar year. Deferred revenues on these arrangements are recorded as contract liabilities. TXNM’s, PNM’s, and TNMP’s contract liabilities and related revenues are not material for any of the periods presented. The Company has no other arrangements with remaining performance obligations to which a portion of the transaction price would be required to be allocated.

(5)Earnings and Dividends Per Share

Basic earnings per share is computed by dividing net earnings attributable to TXNM by the weighted average number of common shares outstanding during the period. Diluted earnings per share was computed by dividing net earnings attributable to TXNM by the diluted weighted average number of common shares outstanding during the period. Diluted earnings per share reflect the potential dilution that could occur if securities or other agreements to issue common stock were settled. TXNM applies the treasury stock method for restricted stock, the 2022 ATM Program, and the 2024 ATM Program. The if-converted method is applied in determining the potential dilutive effect of the conversion of outstanding Convertible Notes.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Information regarding the computation of earnings per share and dividends per share is as follows:


	Year Ended December 31,
	2024		2023		2022
	(In thousands, except per share amounts)
Net Earnings Attributable to TXNM	$	242,154	$	87,818	$	169,530
Average Number of Common Shares:
Outstanding during year	90,214		86,038		85,835
Vested awards of restricted stock	320		258		287
Average Shares – Basic	90,534		86,296		86,122
Dilutive Effect of Common Stock Equivalents:
TXNM ATM Programs	12		38		—

Restricted stock	45		35		47
Average Shares – Diluted	90,591		86,369		86,169
Net Earnings Attributable to TXNM Per Share of Common Stock:
Basic	$	2.67	$	1.02	$	1.97
Diluted	$	2.67	$	1.02	$	1.97
Dividends Declared per Common Share	$	1.57	$	1.49	$	1.41

(6)Stockholders’ Equity

Common Stock and Equity Contributions

On August 2, 2024, TXNM increased the number of authorized shares of the Company’s common stock from 120,000,000 to 200,000,000.

On December 30, 2024, TXNM physically settled 2,458,951 shares sold under forward sales agreements pursuant to the TXNM 2024 ATM Program. The settlement included $0.8 million for issuance costs resulting in net proceeds of $98.6 million. Following this settlement, 1,104,641 shares of TXNM’s common stock remain subject to future settlement under the TXNM 2024 ATM Program.

On December 15, 2023, TXNM physically settled all 4,365,510 shares sold under forward sales agreements pursuant to the TXNM 2022 ATM Program. The settlement included $1.0 million for issuance costs resulting in net proceeds of $198.2 million. Following this settlement, no shares of TXNM’s common stock remained subject to future settlement under the TXNM 2022 ATM Program. TXNM, PNM, and TNMP did not issue any common stock during the years ended December 31, 2022 and 2021.

TXNM funded cash equity contributions to PNM of $55.0 million, zero, and zero in 2024, 2023, and 2022. TXNM funded $24.0 million, $40.9 million, and $68.0 million of cash equity contributions to TNMP in 2024, 2023, and 2022.

Dividends on Common Stock

The declaration of common dividends by TXNM is dependent upon a number of factors, including the ability of TXNM’s subsidiaries to pay dividends. TXNM’s primary sources of dividends are its operating subsidiaries.

PNM declared and paid cash dividends to TXNM of $51.0 million, zero, and $153.5 million in 2024, 2023, and 2022. TNMP did not declare or pay any cash dividends to TXNM in 2024, 2023, or 2022.

The NMPRC has placed certain restrictions on the ability of PNM to pay dividends to TXNM, including the restriction that PNM cannot pay dividends that cause its debt rating to fall below investment grade. The NMPRC provisions allow PNM to pay dividends, with at least 15 days prior notice, from current earnings, which is determined on a rolling four quarter basis, or from equity contributions previously made by TXNM. The Federal Power Act also imposes certain restrictions on dividends by public utilities. Debt-to-capitalization ratio requirements, as discussed in Note 7, remain at less than or equal to 65% for PNM and TNMP and less than or equal to 70% for TXNM. These debt-to-capitalization ratio requirements could limit the amounts of dividends that could be paid. PNM also has other financial covenants that limit the transfer of assets, through dividends or other means, including a requirement to obtain the approval of certain financial counterparties to transfer more than five percent of PNM’s assets. As of December 31, 2024, the 65% debt-to-capitalization covenant would restrict the payment of dividends from the retained earnings of PNM to $509.1 million, and the 65% debt-to-capitalization covenant would

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

restrict the payment of dividends by TNMP to $318.0 million. Similarly, the 70% debt-to-capitalization covenant would restrict the payment of dividends by TXNM to $775.0 million.

In addition, the ability of TXNM to declare dividends is dependent upon the extent to which cash flows will support dividends, the availability of retained earnings, financial circumstances and performance, current and future regulatory decisions, Congressional and legislative acts, and economic conditions. Conditions imposed by the NMPRC or PUCT, future growth plans and related capital requirements, and business considerations may also affect TXNM’s ability to pay dividends.

Preferred Stock

PNM’s cumulative preferred shares outstanding bear dividends at 4.58% per annum. PNM preferred stock does not have a mandatory redemption requirement, but may be redeemed, at PNM’s option, at 102% of the stated value plus accrued dividends. The holders of the PNM preferred stock are entitled to payment before the holders of common stock in the event of any liquidation or dissolution or distribution of assets of PNM. In addition, PNM’s preferred stock is not entitled to a sinking fund and cannot be converted into any other class of stock of PNM.

TXNM and TNMP have no preferred stock outstanding. The authorized shares of TXNM and TNMP preferred stock are 10 million shares and 1 million shares, respectively.

(7)Financing

The Company’s financing strategy includes both short-term and long-term borrowings. The Company utilizes short-term revolving credit facilities, as well as cash flows from operations, to provide funds for both construction and operating expenditures. Depending on market and other conditions, the Company will periodically sell long-term debt or enter into term loan arrangements and use the proceeds to reduce borrowings under the revolving credit facilities or refinance other debt. Each of the Company’s revolving credit facilities, term loans, and other debt agreements contain a single financial covenant that requires the maintenance of a debt-to-capitalization ratio. For the TXNM agreements this ratio must be maintained at less than or equal to 70%, and for the PNM and TNMP agreements this ratio must be maintained at less than or equal to 65%. The Company’s revolving credit facilities, term loans, and other debt agreements generally also contain customary covenants, events of default, cross-default provisions, and change-of-control provisions.

PNM must obtain NMPRC approval for any financing transaction having a maturity of more than 18 months. In addition, PNM files its annual informational financing filing and short-term financing plan with the NMPRC.

Financing Activities

TXNM

At December 31, 2022, TXNM had $1.0 billion outstanding under the 2021 Delayed-Draw Term Loan, among TXNM, the lenders party thereto, and Wells Fargo Bank, N.A., as administrative agent. As discussed below on June 30, 2023, $500.0 million under the TXNM 2021 Delayed Draw Term Loan was prepaid, without penalty, with proceeds from the TXNM 2023 Term Loan. As discussed below, on June 21, 2024, proceeds from the Convertible Notes were used to prepay, without penalty, $449.0 million under the TXNM 2021 Delayed Draw Term Loan. Draws on the TXNM 2021 Delayed-Draw Term Loan bear interest at a variable rate, which was 5.41% at December 31, 2024.

On March 2, 2022, TXNM filed a shelf registration that provides for the issuance of various types of debt and equity securities. The TXNM shelf registration statement expires in March 2025.

On November 10, 2022, TXNM entered into a distribution agreement with BofA Securities, Inc., MUFG Securities Americas Inc. and Wells Fargo Securities, LLC, as sales agents, and Bank of America, N.A., MUFG Securities EMEA plc and Wells Fargo Bank, N.A., as forward purchasers, pursuant to which the Company may sell, from time to time, up to an aggregate

sales price of $200.0 million of its common stock, no par value, through the sales agents (the “TXNM 2022 ATM Program”). Sales of the shares made pursuant to the distribution agreement may be made in “at the market offerings” as defined in Rule 415 of the Securities Act. TXNM did not initially receive any proceeds upon the execution of this agreement.

Throughout 2023, TXNM entered into forward sale agreements, for the sale of shares of TXNM common stock. On December 15, 2023, TXNM physically settled the forward purchases under the TXNM 2022 ATM Program and used the proceeds to repay borrowings under the TXNM Revolving Credit Facility and for other corporate purposes.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Cash proceeds shown below were reduced by $1.0 million in issuance costs resulting in net cash proceeds of $198.2 million.


Forward completion	Initial forward price		Shares	Settlement price		Settlement amount
						(in thousands)
March 15, 2023	$	48.49	504,452	$	49.00	$	24,720
March 20, 2023	48.30		528,082	48.78		25,758
May 30, 2023	47.56		244,639	47.99		11,741
June 30, 2023	44.87		804,477	45.07		36,257
September 26, 2023	44.03		2,283,860	44.11		100,734
			4,365,510			$	199,210

On June 30, 2023, TXNM entered into a $500.0 million term loan agreement (the “TXNM 2023 Term Loan”) among TXNM, the lenders party thereto, and Wells Fargo Bank, N.A., as administrative agent. The proceeds were used to prepay an equal amount of the TXNM 2021 Delayed Draw Term Loan, without penalty. As discussed below, on June 21, 2024, proceeds from the Convertible Notes were used to prepay, without penalty, $90.0 million under the TXNM 2023 Term Loan. The TXNM 2023 Term Loan matures on June 30, 2026 and bears interest at a variable rate, which was 5.81% at December 31, 2024.

On May 6, 2024, TXNM entered into a distribution agreement with BofA Securities, Inc., Citigroup Global Markets, Inc., MUFG Securities Americas Inc., RBC Capital Markets, LLC, Scotia Capital (USA) Inc., and Wells Fargo Securities, LLC, as sales agents, and Bank of America, N.A., Citibank, N.A., MUFG Securities EMEA plc, Royal Bank of Canada, The Bank of Nova Scotia, and Wells Fargo Bank, N.A., as forward purchasers, pursuant to which the Company may sell, from time to time, up to an aggregate sales amount of $100.0 million of its common stock, no par value, through the sales agents (the “TXNM 2024 ATM Program”). On August 5, 2024, subsequent to approval by shareholders to increase TXNM’s authorized shares, the Company amended the distribution agreement increasing the aggregate sales amount from $100.0 million to $300.0 million of its common stock, no par value, that may be sold under the TXNM 2024 ATM Program. Sales of the shares made pursuant to the distribution agreement may be made in “at the market offerings” as defined in Rule 415 of the Securities Act. TXNM did not initially receive any proceeds upon the execution of this agreement.

TXNM entered into forward sales agreements with forward purchasers relating to the sale of 262,025 shares of common stock, at an initial forward sale price of $37.77 per share in the second quarter; 2,196,926 shares of common stock at a weighted average initial forward sale price of $40.58 per share in the third quarter; and 1,104,641 shares of common stock at a weighted average initial forward sale price of $44.83 per share in the fourth quarter. All initial forward prices under the agreements are subject to adjustments based on a net interest rate factor and by future dividends paid on TXNM common stock. On December 30, 2024, TXNM physically settled forward purchases under the TXNM 2024 ATM Program for 2,458,951 shares and used the proceeds to repay borrowings under the TXNM Revolving Credit Facility. Cash proceeds shown below were reduced by $0.8 million in issuance costs resulting in net cash proceeds of $98.6 million.


Forward completion	Initial forward price		Shares	Settlement price		Settlement amount
						(in thousands)
May 13, 2024	$	37.76	262,025	$	38.01	$	9,960
August 13, 2024	39.98		113,014	40.21		4,545
August 16, 2024	40.26		261,066	40.48		10,568
August 23, 2024	40.36		284,952	40.56		11,558
August 30, 2024	40.47		311,583	40.64		12,661
September 16, 2024	40.77		1,226,311	40.85		50,093
			2,458,951			$	99,385

As of December 31, 2024, 1,104,641 shares under forward sales agreements under the 2024 TXNM ATM Program remained unsettled.

On June 10, 2024, TXNM issued $500.0 million aggregate principal amount of junior subordinated convertible notes due 2054 (the “Convertible Notes”) in a private offering to qualified institutional buyers pursuant to Rule 144A under the Securities Act. The Convertible Notes are unsecured obligations of the Company and rank junior and subordinate in right of payment to the prior payment in full of the Company’s existing and future senior indebtedness. The Convertible Notes bear interest at a rate of 5.75% per year, payable semi-annually in arrears on June 1 and December 1, and mature on June 1, 2054, unless earlier

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

converted, redeemed, or repurchased in accordance with their terms. On June 21, 2024, TXNM issued an additional $50.0 million aggregate principal amount of the Convertible Notes, pursuant to an overallotment option granted by TXNM to the initial purchasers of the $500.0 million Convertible Notes. Proceeds from the Convertible Notes were used to prepay $449.0 million of borrowings under the TXNM 2021 Delayed Draw Term Loan and $90.0 million of borrowings under the TXNM 2023 Term Loan, without penalty, and for other corporate purposes.

TXNM may not redeem the Convertible Notes prior to June 6, 2029, except upon the occurrence of certain tax events, rating agency events or treasury stock events (each, a “special event”). TXNM may redeem for cash all, but not less than all, of the Convertibles Notes upon the occurrence of a special event at any time, at its option, at a redemption price equal to 100% of the principal amount of the Convertible Notes to be redeemed, plus accrued and unpaid interest to, but excluding, the redemption date. In addition, TXNM may redeem for cash all or part (subject to certain limitations on partial redemptions) of the Convertible Notes, at its option, on or after June 6, 2029, at a redemption price equal to 100% of the principal amount of the convertible notes to be redeemed, plus accrued and unpaid interest to, but excluding, the redemption date, if the last reported sale price of TXNM’s common stock has been at least 130% of the conversion price of the convertible notes then in effect for at least 20 trading days (whether or not consecutive) during any 30 consecutive trading day period (including the last trading day of such period) ending on, and including, the trading day immediately preceding the date on which TXNM provides notice of redemption. In each case, TXNM will not, and will not be permitted to, issue a notice of redemption, or specify a redemption date, during any interest deferral period.

Prior to the close of business on the business day immediately preceding December 1, 2053, the Convertible Notes will be convertible at the option of the holders only under certain conditions. On or after December 1, 2053 until the close of business on the second business day immediately preceding the maturity date, holders may convert all or any portion of their Convertible Notes at their option, at any time, at the conversion rate then in effect, irrespective of these conditions. Upon conversion of the Convertible Notes, TXNM will pay cash, or deliver an equal aggregate principal amount of a newly issued series of its nonconvertible junior subordinated notes with the same terms as the Convertible Notes (other than the conversion features and certain features in relation to redemption rights), in either case, up to the aggregate principal amount of the Convertible Notes being converted, and deliver shares of TXNM’s common stock in respect of the remainder, if any, of TXNM’s conversion obligation in excess of the aggregate principal amount of the Convertible Notes being converted.

The conversion rate for the Convertible Notes will initially be 22.4911 shares of TXNM’s common stock per $1,000 principal amount of the Convertible Notes, equivalent to an initial conversion price of $44.46 per share of common stock. The initial conversion price of the Convertible Notes represents a conversion premium of 17.5% above the last reported sale price of TXNM’s common stock on June 4, 2024. The conversion rate and the corresponding conversion price will be subject to adjustment by certain events such as increased dividends but will not adjust for any accrued or unpaid interest. In addition, following certain corporate events that occur prior to the maturity date of the Convertible Notes or if TXNM delivers a notice of a special event redemption, TXNM will, in certain circumstances, increase the conversion rate for a holder that elects to convert its Convertible Notes in connection with such a corporate event or such notice of special event redemption, as the case may be.

TXNM issued the Convertible Notes pursuant to an indenture (the “Convertible Notes Indenture”) dated as of June 10, 2024 between TXNM and Computershare Trust Company, N.A., as trustee. The Convertible Notes are subject to continuing compliance with the representations, warranties, and covenants set forth in the Convertible Notes Indenture, which include the customary covenants discussed above. In the event of a fundamental change, as defined in the Convertible Notes Indenture, TXNM may be required to repurchase, for cash, the aggregate principal amount of Convertible Notes plus accrued interest. TXNM may not redeem the Convertible notes prior to June 6, 2029 except upon the occurrence of a special event as defined in the Convertible Notes Indenture.

So long as no event of default with respect to the Convertible Notes has occurred and is continuing, TXNM may, at its option, defer interest payments on the Convertible Notes on one or more occasions for up to 20 consecutive semi-annual interest payment periods. During any deferral period, interest on the Convertible Notes will continue to accrue at the then-applicable interest rate on the Convertible Notes. In addition, during any deferral period, interest on deferred interest will accrue at the then-applicable interest rate on the Convertible Notes, compounded semi-annually, to the extent permitted by applicable law.

PNM

On June 18, 2021, PNM entered into a $75.0 million term loan agreement (the “PNM 2021 Term Loan”) between PNM and Bank of America, N.A., as lender. The PNM 2021 Term Loan was used to repay the PNM 2019 $40.0 million Term Loan

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

and for other corporate purposes. On August 5, 2022, the PNM 2021 Term Loan was prepaid without penalty with proceeds from the PNM 2022 Delayed-Draw Term Loan discussed below.

At December 31, 2021, PNM had $104.5 million PCRBs outstanding with a mandatory remarketing date of June 1, 2022, consisting of $36.0 million at 1.05% issued by the Maricopa County, Arizona Pollution Control Corporation with a final maturity of January 2038; $37.0 million at 2.125% issued by the City of Farmington, New Mexico with a final maturity of June 2040; $11.5 million at 1.20% issued by the City of Farmington, New Mexico with a final maturity of June 2040; and $20.0 million at 2.45% issued by the City of Farmington, New Mexico with a final maturity of September 2042. On June 1, 2022, PNM remarketed to new investors the $36.0 million and $37.0 million series in the tax-exempt market at 3.00% with a mandatory remarketing date of June 1, 2024. PNM purchased and redeemed the remaining two series of PCRBs, totaling $31.5 million, on June 1, 2022.

On August 5, 2022, PNM entered into a $225.0 million delayed-draw term loan agreement (the “PNM 2022 Delayed-Draw Term Loan”), among PNM, the lender parties thereto, and Royal Bank of Canada, as administrative agent. PNM initially drew $180.0 million to prepay, without penalty, the $75.0 million PNM 2021 Term Loan ahead of its December 2022 maturity and for other corporate purposes. On September 30, 2022, PNM drew the remaining $45.0 million and used the proceeds for general corporate purposes. On November 15, 2023, upon receipts of funds from the sale of energy transition property to ETBC I discussed below, PNM prepaid the $225.0 million outstanding under the PNM 2022 Delayed-Draw Term Loan, without penalty.

At December 31, 2022, PNM had $130.0 million of 1.10% PCRBs outstanding with a mandatory remarketing date of June 1, 2023, issued by the City of Farmington, New Mexico with a final maturity of June 2040. On June 1, 2023, PNM remarketed the $130.0 million to new investors at 3.90% with a mandatory tender date of June 1, 2028.

At December 31, 2022, PNM had $55.0 million aggregate principal amount of its 3.15% SUNs outstanding due May 2023. On May 15, 2023, PNM repaid the $55.0 million 3.15% SUNs.

On April 28, 2023, PNM entered into an agreement (the “PNM 2023 Note Purchase Agreement”) with institutional investors for the sale and issuance of $200.0 million aggregate principal amount of two series of SUNs (the “PNM 2023 SUNs”) offered in private placement transactions. The PNM 2023 SUNs were issued on April 28, 2023. PNM issued $150.0 million of the PNM 2023 SUNs at 5.51%, due April 28, 2035, and another $50.0 million at 5.92%, due April 28, 2053. Proceeds from the PNM 2023 SUNs were used to repay borrowings under the PNM Revolving Credit Facility and the PNM New Mexico Credit Facility, for funding of capital expenditures, and for general corporate purposes. The PNM 2023 Note Purchase Agreement includes the customary covenants discussed above. In the event of a change of control, PNM will be required to offer to prepay the PNM 2023 SUNs at par. PNM has the right to redeem any or all of the PNM 2023 SUNs prior to their maturities, subject to payment of a customary make-whole premium.

On May 10, 2024, PNM entered into a $200.0 million term loan agreement (the “PNM 2024 Term Loan”), among PNM, the lenders party thereto and U.S. Bank National Association, as administrative agent. PNM used the proceeds of the PNM 2024 Term Loan to repay borrowings under the PNM Revolving Credit Facility, the PNM New Mexico Credit Facility, and for general corporate purposes. The PNM 2024 Term Loan bears interest at a variable rate, which was 5.40% at December 31, 2024, and must be repaid on or before November 10, 2025.

At December 31, 2023, PNM had outstanding $37.0 million of 3.00% PCRBs and $125.0 million of 1.15% PCRBs issued by the City of Farmington, New Mexico with a mandatory remarketing date of June 1, 2024 and final maturities of June 2040 and $36.0 million of 3.00% PCRBs issued by Maricopa County, Arizona with a mandatory remarketing date of June 1, 2024 and a final maturity of January 2038. On June 3, 2024, PNM remarketed these PCRBs aggregating $198.0 million to new investors at 3.875% with a mandatory tender date of June 1, 2029.

On January 21, 2025, PNM entered into a $195.0 million term loan agreement (the “PNM 2025 Term Loan”), among PNM, the lenders party thereto and Canadian Imperial Bank of Commerce, New York Branch, as administrative agent. PNM used the proceeds of the PNM 2025 Term Loan to repay borrowings under the PNM Revolving Credit Facility, the PNM New Mexico Credit Facility, and for general corporate purposes. The PNM 2025 Term Loan bears interest at a variable rate and must be repaid on or before July 21, 2026.

ETBC I

On November 15, 2023, ETBC I issued $343.2 million aggregate principal amount of its senior secured energy transition bonds, Series A (“ETBC I Securitized Bonds”) in two tranches. The first tranche of $175.0 million aggregate principal amount

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

was issued at an interest rate of 5.64% with an expected final payment due in August 2040. The second tranche of $168.2 million aggregate principal amount was issued at an interest rate of 6.03% with an expected final payment due in August 2048. Each tranche is subject to fixed, scheduled, semi-annual payments of principal and interest beginning on August 15, 2024 with $6.9 million included as Current installments of long-term debt on the Consolidated Balance Sheets at December 31, 2024. The ETBC I Securitized Bonds were offered pursuant to a prospectus dated November 7, 2023 and are governed by an indenture between ETBC I and U.S. Bank Trust Company, National Association, as indenture trustee dated as of November 15, 2023. ETBC I used the proceeds from the issuance of the ETBC I Securitized Bonds to purchase energy transition property (Note 16) from PNM. See Note 10.

TNMP

On April 27, 2022, TNMP entered into an agreement (the “TNMP 2022 Bond Purchase Agreement”) with institutional investors for the sale of $160.0 million aggregate principal amount of two series of TNMP first mortgage bonds (the “TNMP 2022 Bonds”) offered in private placement transactions. TNMP issued the first series of $65.0 million of the TNMP 2022 Bonds on May 12, 2022, at a 4.13% interest rate, due May 12, 2052, and the second series of $95.0 million of the TNMP 2022 Bonds on July 28, 2022, at a 3.81% interest rate, due July 28, 2032. The proceeds were used to repay borrowings under the TNMP Revolving Credit Facility and for other corporate purposes. The TNMP 2022 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the supplemental indenture governing the TNMP 2022 Bonds. The terms of the supplemental indentures governing the TNMP 2022 Bonds include the customary covenants discussed above. In the event of a change of control, TNMP will be required to offer to prepay the TNMP 2022 Bonds at par. TNMP has the right to redeem any or all of the TNMP 2022 Bonds prior to their maturity, subject to payment of a customary make-whole premium.

On April 28, 2023, TNMP entered into an agreement (the “TNMP 2023 Bond Purchase Agreement”) with institutional investors for the sale of $185.0 million aggregate principal amount of two series of TNMP first mortgage bonds (the “TNMP 2023 Bonds”) offered in private placement transactions. TNMP issued the first series of $130.0 million on April 28, 2023, at a 5.01% interest rate, due April 28, 2033. The second series of $55.0 million was issued on July 28, 2023, at a 5.47% interest rate, due July 28, 2053. The proceeds were used to repay borrowings under the TNMP Revolving Credit Facility, for funding of capital expenditures, and for other corporate purposes. The TNMP 2023 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the supplemental indentures governing the TNMP 2023 Bonds. The terms of the supplemental indentures governing the TNMP 2023 Bonds include the customary covenants discussed above. In the event of a change of control, TNMP will be required to offer to prepay the TNMP 2023 Bonds at par. TNMP has the right to redeem any or all of the TNMP 2023 Bonds prior to their maturity, subject to payment of a customary make-whole premium.

On March 28, 2024, TNMP entered into an agreement (the “TNMP 2024 Bond Purchase Agreement”) with institutional investors for the sale of $285.0 million aggregate principal amount of four series of TNMP first mortgage bonds (the “TNMP 2024 Bonds”) offered in private placement transactions. TNMP issued the first two series on March 28, 2024, consisting of $32.0 million at a 5.26% interest rate, due March 28, 2029, and $85.0 million at a 5.55% interest rate, due March 28, 2036. The third and fourth series were issued on July 1, 2024, consisting of $40.0 million at a 5.65% interest rate, due July 1, 2039, and $128.0 million at a 5.79% interest rate, due July 1, 2054. The proceeds were used to repay existing debt, including the $80.0 million of 4.03% TNMP FMBs that were due July 2024 and borrowings under the TNMP Revolving Credit Facility, for funding of capital expenditures, and for other corporate purposes. The TNMP 2024 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the supplemental indentures governing the TNMP 2024 Bonds. The terms of the supplemental indentures governing the TNMP 2024 Bonds include the customary covenants discussed above. In the event of certain changes of control of TXNM or TNMP, TNMP will be required to offer to prepay the TNMP 2024 Bonds at par. TNMP has the right to redeem any or all of the TNMP 2024 Bonds prior to their maturity, subject to payment of a customary make-whole premium.

On February 14, 2025, TNMP entered into an agreement (the “TNMP 2025 Bond Purchase Agreement”) with institutional investors for the sale of $140.0 million aggregate principal amount of its 5.19% TNMP first mortgage bonds (the “TNMP 2025 Bonds”) offered in private placement transactions. TNMP issued all $140.0 million at a 5.19% interest rate, due April 1, 2031. The proceeds were used to repay borrowings under the TNMP Revolving Credit Facility, for funding of capital expenditures, and for other corporate purposes. The TNMP 2025 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the supplemental indentures governing the TNMP 2025 Bonds. The terms of the supplemental indentures governing the TNMP 2025 Bonds include the customary covenants discussed above. In the event of a change of control, TNMP will be required to offer to prepay the TNMP 2025 Bonds at par. TNMP has the right to redeem any or all of the TNMP 2025 Bonds prior to their maturity, subject to payment of a customary make-whole premium.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Interest Rate Hedging Activities

TXNM has entered into hedging agreements that establish a fixed rate for the indicated amount of variable rate debt, above which a customary spread is applied, which is subject to change if there is a change in TXNM’s credit rating. As of December 31, 2023, TXNM’s hedging agreements were as follows:


		Variable Rate		Established
Effective Date	Maturity Date	Debt Hedged		Fixed Rate
		(In millions)		(Percent)
March 17, 2023	September 30, 2023	$	150.0	4.57	%
October 31, 2022	December 31, 2023	100.0		4.65
October 31, 2022	December 31, 2023	100.0		4.66
September 30, 2022	December 31, 2023	100.0		4.17
September 30, 2022	December 31, 2023	100.0		4.18
May 20, 2022	December 31, 2023	100.0		2.52
May 2, 2022	December 31, 2023	150.0		2.65
May 2, 2022	December 31, 2023	200.0		2.65
January 1, 2024	December 31, 2024	100.0		3.32
January 1, 2024	December 31, 2024	100.0		3.32
January 1, 2024	December 31, 2024	100.0		3.38
January 1, 2024	December 31, 2024	150.0		3.62
January 1, 2024	December 31, 2024	150.0		3.57
January 1, 2025	December 31, 2025	100.0		4.18
January 1, 2025	December 31, 2025	100.0		4.18
January 1, 2025	December 31, 2025	100.0		3.99

Throughout 2023 and 2024, these hedging agreements were accounted for as cash flow hedges. At December 31, 2023, the fair value of the active hedging agreements was a gain of $7.2 million that was included in Other current assets and a loss of $2.3 million that was included in Other deferred credits on the Consolidated Balance Sheets. Fair values were determined using Level 2 inputs under GAAP, including using forward SOFR curves under the mid-market convention to discount cash flows over the remaining term of the agreements. In November 2024, TXNM unwound and settled the $300.0 million of hedging agreements that were expected to mature on December 31, 2025, and on December 31, 2024, the remaining $600.0 million of hedging agreements matured. TXNM had no active hedging agreements at December 31, 2024.

Borrowing Arrangements Between TXNM and its Subsidiaries

TXNM has intercompany loan agreements with its subsidiaries. Individual subsidiary loan agreements vary in amount up to $150.0 million and have either reciprocal or non-reciprocal terms. Interest charged to the subsidiaries is equivalent to interest paid by TXNM on its short-term borrowings or the money-market interest rate if TXNM does not have any short-term borrowings outstanding. All balances outstanding under intercompany loan agreements are eliminated upon consolidation. See Note 1. PNM and TNMP had no borrowings from TXNM at December 31, 2024 and 2023. PNMR Development had zero and $2.3 million in short-term borrowings outstanding from TXNM at December 31, 2024 and 2023. TXNM had $1.5 million and zero in short-term borrowings outstanding from PNMR Development at December 31, 2024 and 2023.

Short-term Debt and Liquidity

As of December 31, 2024, the TXNM Revolving Credit Facility had a financing capacity of $300.0 million and the PNM Revolving Credit Facility had a financing capacity of $400.0 million. On April 1, 2024, TXNM and PNM amended their respective revolving credit facilities, extending their maturity to March 30, 2029, with two one-year extension options that, if exercised, would extend the maturity to March 2031, subject to approval by a majority of the lenders. PNM also has the $40.0 million PNM New Mexico Credit Facility with a maturity of May 20, 2026. As of December 31, 2023, the TNMP Revolving Credit Facility had a capacity of $100.0 million, secured by $100.0 million aggregate principal amount of TNMP first mortgage bonds. On April 1, 2024, TNMP entered into a new $200.0 million Revolving Credit Facility that replaced the $100.0 million Revolving Credit Facility. The new $200.0 million Revolving Credit Facility is secured by $200.0 million aggregate principal amount of TNMP first mortgage bonds and has a maturity of March 30, 2029, with two one-year extension options that, if exercised, would extend the maturity to March 2031, subject to approval by a majority of the lenders. Variable interest rates under the TXNM, PNM, and TNMP revolving credit facilities are based on SOFR.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Short-term debt outstanding consists of:


	December 31,
Short-term Debt	2024		2023
	(In thousands)
PNM:
PNM Revolving Credit Facility	$	323,800	$	107,500
PNM New Mexico Credit Facility	40,000		30,000
	363,800		137,500
TNMP Revolving Credit Facility	151,600		55,100
TXNM:
TXNM Revolving Credit Facility	93,900		69,300



	$	609,300	$	261,900

In addition to the above borrowings, TXNM, PNM, and TNMP had letters of credit outstanding of $3.1 million, zero, and zero at December 31, 2024, that reduce the available capacity under their respective revolving credit facilities. TXNM also has $30.3 million of letters of credit outstanding under the WFB LOC Facility. At December 31, 2024, interest rates on outstanding borrowings were 5.73% for the PNM Revolving Credit Facility, 5.81% for the PNM New Mexico Credit Facility, 5.37% for the TNMP Revolving Credit Facility, and 5.96% for the TXNM Revolving Credit Facility.

Long-Term Debt

Information concerning long-term debt outstanding and unamortized (premiums), discounts, and debt issuance costs is as follows:


	December 31, 2024				December 31, 2023
	Principal		Unamortized Discounts, (Premiums), and Issuance Costs, net		Principal		Unamortized Discounts, (Premiums), and Issuance Costs, net
	(In thousands)
PNM Debt

ETBC I - Senior Secured Energy Transition Bonds
Series A-1, 5.64%	$	172,471	$	1,025	$	175,000	$	1,093
Series A-2, 6.03%	168,200		1,014		168,200		1,057

Senior Unsecured Notes, Pollution Control Revenue Bonds:

2.15% due April 2033	146,000		736		146,000		824





3.00% due June 2040, mandatory tender - June 1, 2024	—		—		37,000		88




0.875% mandatory tender - October 1, 2026	100,345		257		100,345		403

3.00% due January 2038, mandatory tender - June 1, 2024	—		—		36,000		87


1.15% due June 2040, mandatory tender - June 1, 2024	—		—		125,000		132
3.90% due June 2040, mandatory tender - June 1, 2028	130,000		796		130,000		1,029
3.875% due June 2040, mandatory tender - June 1, 2029	162,000		1,158		—		—
3.875% due January 2038, mandatory tender - June 1, 2029	36,000		258		—		—





Senior Unsecured Notes:




3.45% due May 2025	104,000		39		104,000		143
3.85% due August 2025	250,000		174		250,000		477
3.68% due May 2028	88,000		209		88,000		271
3.78% due August 2028	15,000		38		15,000		48
3.93% due May 2033	38,000		149		38,000		167
4.22% due May 2038	45,000		212		45,000		228
4.50% due May 2048	20,000		110		20,000		114
4.60% due August 2048	85,000		470		85,000		490
3.21% due April 2030	150,000		852		150,000		1,011
3.57% due April 2039	50,000		398		50,000		426




2.59% due July 2033	80,000		328		80,000		366

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022


	December 31, 2024				December 31, 2023
	Principal		Unamortized Discounts, (Premiums), and Issuance Costs, net		Principal		Unamortized Discounts, (Premiums), and Issuance Costs, net
	(In thousands)
PNM Debt (Continued)
3.14% due July 2041	80,000		381		80,000		404
2.29% due December 2031	50,000		205		50,000		235
2.97% due December 2041	100,000		499		100,000		528
5.51% due April 2035	150,000		779		150,000		854
5.92% due April 2053	50,000		280		50,000		290
PNM 2024 $200.0 Million Term Loan due November 2025	200,000		57		—		—
	2,470,016		10,424		2,272,545		10,765
Less current maturities	560,907		270		200,529		307
	1,909,109		10,154		2,072,016		10,458




TNMP Debt
First Mortgage Bonds:

6.95% due April 2043	93,198		(13,056)		93,198		(13,771)
4.03% due July 2024	—		—		80,000		53
3.53% due February 2026	60,000		91		60,000		174
3.22% due August 2027	60,000		152		60,000		209
3.85% due June 2028	60,000		219		60,000		281
3.79% due March 2034	75,000		347		75,000		385
3.92% due March 2039	75,000		401		75,000		429
4.06% due March 2044	75,000		433		75,000		456
3.60% due July 2029	80,000		270		80,000		330
2.73% due April 2030	85,000		445		85,000		530
3.36% due April 2050	25,000		210		25,000		218
2.93% due July 2035	25,000		175		25,000		191
3.36% due July 2050	50,000		424		50,000		441
2.44% due August 2035	65,000		382		65,000		418
4.13% due May 2052	65,000		409		65,000		424
3.81% due July 2032	95,000		505		95,000		572
5.01% due April 2033	130,000		610		130,000		682
5.47% due July 2053	55,000		286		55,000		296
5.26% due March 2029	32,000		189		—		—
5.55% due March 2036	85,000		538		—		—
5.65% due July 2039	40,000		256		—		—
5.79% due July 2054	128,000		833		—		—
	1,458,198		(5,881)		1,253,198		(7,682)
Less current maturities	—		—		80,000		53
	1,458,198		(5,881)		1,173,198		(7,735)




TXNM Debt


TXNM 2021 Delayed-Draw Term Loan due May 2025	51,000		34		500,000		114
TXNM 2023 Term Loan due June 2026	410,000		441		500,000		735
5.75% TXNM Junior Subordinated Convertible Notes due June 2054	550,000		10,828		—		—
	1,011,000		11,303		1,000,000		849
Less current maturities	51,000		34		—		—
	960,000		11,269		1,000,000		849
Total Consolidated TXNM Debt	4,939,214		15,846		4,525,743		3,932
Less current maturities	611,907		304		280,529		360
	$	4,327,307	$	15,542	$	4,245,214	$	3,572

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Table of Contents

TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Reflecting mandatory tender dates, long-term debt maturities as of December 31, 2024, are follows:


	TXNM		PNM		TNMP		TXNM Consolidated
	(In thousands)
2025	$	51,000	$	560,907	$	—	$	611,907
2026	410,000		107,648		60,000		577,648
2027	—		7,721		60,000		67,721
2028	—		241,162		60,000		301,162
2029	—		206,629		112,000		318,629
Thereafter	550,000		1,345,949		1,166,198		3,062,147
Total	$	1,011,000	$	2,470,016	$	1,458,198	$	4,939,214

(8)Lease Commitments

The Company enters into various lease agreements to meet its business needs and to satisfy the needs of its customers. The Company accounts for contracts that convey the use and control of identified assets for a period of time as leases. The Company classifies leases as operating or financing by evaluating the terms of the lease agreement. Agreements under which the Company is likely to utilize substantially all of the economic value or life of the asset or that the Company is likely to own at the end of the lease term, either through purchase or transfer of ownership, are classified as financing leases. Leases not meeting these criteria are accounted for as operating leases. Agreements under which the Company is a lessor are insignificant. TXNM, PNM, and TNMP determine present value for their leases using their incremental borrowing rates at the commencement date of the lease or, when readily available, the rate implicit in the agreement. The Company leases office buildings, vehicles, energy storage facilities, and other equipment. In addition, PNM had lease interests in PVNGS and certain rights-of-way agreements that are classified as leases. All of the Company’s leases with fixed-payment terms in excess of one year are recorded on the Consolidated Balance Sheets by recording a present value lease liability and a corresponding right-of-use asset. Operating lease expense is recognized within operating expenses according to the use of the asset on a straight-line basis. Financing lease costs, which are comprised primarily of fleet and office equipment leases commencing after January 1, 2019, are recognized by amortizing the right-of-use asset on a straight-line basis and by recording interest expense on the lease liability. Financing lease right-of-use assets amortization is reflected in depreciation and amortization and interest on financing lease liabilities is reflected as interest charges on the Company’s Consolidated Statements of Earnings.

PVNGS

In 1985 and 1986, PNM entered into leases for its interest in PVNGS Unit 1 and 2. The leases initially were scheduled to expire in January 2015 for four Unit 1 leases and January 2016 for four Unit 2 leases. Following procedures set forth in the PVNGS leases, PNM notified four of the lessors under the Unit 1 leases and one lessor under the Unit 2 lease that it would elect to renew those leases on the expiration date of the original leases. The four Unit 1 leases expired in January 2023 and the one Unit 2 lease expired in January 2024. PNM has no further lease payments related to PVNGS Unit 1 or 2.

On April 5, 2021, PNM and Salt River Project entered into an Asset Purchase and Sale Agreement, pursuant to which PNM agreed to sell to Salt River Project certain PNM-owned assets and nuclear fuel necessary to the ongoing operation and maintenance of leased capacity in PVNGS Unit 1 and Unit 2. In January 2023, the Unit 1 leases expired, and PNM closed on the associated sale to Salt River Project, receiving payments of $33.7 million, of which $28.4 million was recorded as a reduction to Net utility plant on the Consolidated Balance Sheets and is presented as cash flows from investing activities on the Consolidated Statement of Cash Flows. In addition, $5.3 million was recorded as a reduction to materials, supplies, and fuel stock on the Consolidated Balance Sheets and is presented as cash flows from operating activities on the Consolidated Statement of Cash Flows. In January 2024, the Unit 2 leases expired, and PNM closed on the associated sale to Salt River Project, receiving payments of $3.4 million, of which $2.8 million was recorded as a reduction to Net utility plant on the Consolidated Balance Sheets and is presented as cash flows from investing activities on the Consolidated Statement of Cash Flows. In addition, $0.6 million was recorded as a reduction to Materials, supplies and fuel stock on the Consolidated Balance Sheets and is presented as cash flows from operating activities on the Consolidated Statement of Cash Flows.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Land Easements and Rights-of-Ways

Many of PNM’s electric transmission and distribution facilities are located on lands that require the grant of rights-of-way from governmental entities, Native American tribes, or private parties. PNM has completed several renewals of rights-of-way, the largest of which is a renewal with the Navajo Nation. PNM is obligated to pay the Navajo Nation annual payments of $6.0 million, subject to adjustment each year based on the Consumer Price Index, through 2029. PNM’s April 2024 payment for the amount due under the Navajo Nation right-of-way lease was $8.6 million, which included amounts due under the Consumer Price Index adjustment. Changes in the Consumer Price Index subsequent to January 1, 2019, are considered variable lease payments.

PNM has other prepaid rights-of-way agreements that are not accounted for as leases or recognized as a component of plant in service. PNM reflects the unamortized balance of these prepayments in other deferred charges on the Consolidated Balance Sheets and recognizes amortization expense associated with these agreements in the Consolidated Statement of Earnings over their term. As of December 31, 2024 and 2023, the unamortized balance of these rights-of-ways was $67.1 million and $56.2 million. During the years ended December 31, 2024, 2023, and 2022, PNM recognized amortization expense associated with these agreements of $4.3 million, $3.5 million, and $3.8 million.

Fleet Vehicles and Equipment

Fleet vehicle and equipment leases commencing on or after January 1, 2019, are classified as financing leases. Fleet vehicle and equipment leases existing as of December 31, 2018, are classified as operating leases. The Company’s fleet vehicle and equipment lease agreements include non-lease components for insignificant administrative and other costs that are billed over the life of the agreement. At December 31, 2024, residual value guarantees on fleet vehicle and equipment leases are $0.7 million, $0.9 million, and $1.6 million for PNM, TNMP, and TXNM Consolidated.

Energy Storage Agreements

PNM has entered into various ESAs with fixed payments over the life of the agreements. These types of agreements are accounted for as operating leases. In the fourth quarter of 2024, an energy storage facility with an aggregate capacity of 100 MW began commercial operation and PNM recorded lease liabilities with a corresponding right-of-use asset of $101.5 million. PNM has also entered into ESAs with monthly payments that vary depending on the available capacity of the storage facility. These types of ESAs are accounted for as operating leases with variable consideration and do not require a lease liability or right-of-use asset. In the fourth quarter of 2024, a 300MW energy storage agreement with payments that depend on available capacity began commercial operation. The expense for this lease is reflected in variable lease expense in the tables below. In addition, the Company has elected to separate lease components from non-lease components for ESAs and accordingly, does not include non-lease components in the measurement of the lease liability or right-of-use asset. The non-lease components which are not included in the measurement of the lease liability or the corresponding right-of-use asset, comprises of 25.5% of the value of the agreements.

Information related to the Company’s operating leases recorded on the Consolidated Balance Sheets is presented below:


	December 31, 2024						December 31, 2023
	PNM		TNMP		TXNM Consolidated		PNM		TNMP		TXNM Consolidated
	(In thousands)
Operating leases:
Operating lease assets, net of amortization	$	271,433	$	923	$	272,894	$	180,370	$	1,814	$	182,201
Current portion of operating lease liabilities	13,542		713		14,293		11,371		895		12,267
Long-term portion of operating lease liabilities	254,702		167		255,376		166,191		809		167,000

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

As discussed above, the Company classifies its fleet vehicle and equipment leases and its office equipment leases commencing on or after January 1, 2019, as financing leases. Information related to the Company’s financing leases recorded on the Consolidated Balance Sheets is presented below:


	December 31, 2024						December 31, 2023
	PNM		TNMP		TXNM Consolidated		PNM		TNMP		TXNM Consolidated
	(In thousands)
Financing leases:
Non-utility property	$	24,548	$	24,420	$	50,144	$	25,425	$	24,487	$	49,981
Accumulated depreciation	(10,997)		(13,411)		(24,604)		(11,984)		(11,869)		(23,905)
Non-utility property, net	$	13,551	$	11,009	$	25,540	$	13,441	$	12,618	$	26,076

Other current liabilities	$	4,311	$	4,527	$	9,126	$	4,146	$	4,616	$	8,776
Other deferred credits	9,262		6,504		16,470		9,300		8,023		17,326

Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities is presented below:


	December 31, 2024						December 31, 2023
	PNM		TNMP		TXNM Consolidated		PNM		TNMP		TXNM Consolidated
Weighted average remaining lease term (years):
Operating leases	17.52		1.10		17.45		16.79		1.65		16.65
Financing leases	3.51		2.80		3.20		3.81		3.08		3.45

Weighted average discount rate:
Operating leases	5.68	%	4.41	%	5.68	%	5.61	%	4.16	%	5.60	%
Financing leases	5.08		5.19		5.12		4.54		4.63		4.58

Information for the components of lease expense is as follows:


	Year Ended December 31, 2024
	PNM		TNMP		TXNM Consolidated
	(In thousands)
Operating lease cost:
Energy storage leases	$	13,353	$	—	$	13,353
Other operating leases	7,722		907		8,679
Amounts capitalized	(101)		(793)		(894)
Total operating lease expense	20,974		114		21,138
Financing lease cost:
Amortization of right-of-use assets	4,554		5,129		9,889
Interest on lease liabilities	603		595		1,229
Amounts capitalized	(3,227)		(4,648)		(7,875)
Total financing lease expense	1,930		1,076		3,243
Variable lease expense	3,900		—		3,900
Short-term lease expense	714		23		787
Total lease expense for the period	$	27,518	$	1,213	$	29,068

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022


	Year Ended December 31, 2023
	PNM		TNMP		TXNM Consolidated
	(In thousands)
Operating lease cost
Energy storage leases	$	4,351	$	—	$	4,351
Other operating leases	11,127		1,479		12,606
Amounts capitalized	(374)		(1,298)		(1,672)
Total operating lease expense	15,104		181		15,285
Financing lease cost:
Amortization of right-of-use assets	4,566		4,634		9,253
Interest on lease liabilities	562		497		1,060
Amounts capitalized	(3,190)		(4,250)		(7,440)
Total financing lease expense	1,938		881		2,873
Variable lease expense	1,342		—		1,342
Short-term lease expense	675		29		782
Total lease expense for the period	$	19,059	$	1,091	$	20,282


	Year Ended December 31, 2022
	PNM		TNMP		TXNM Consolidated
	(In thousands)
Operating lease cost
Other operating leases	$	26,764	$	2,020	$	28,835
Amounts capitalized	(690)		(1,728)		(2,417)
Total operating lease expense	26,074		292		26,418
Financing lease cost:
Amortization of right-of-use assets	3,175		3,279		6,529
Interest on lease liabilities	327		330		659
Amounts capitalized	(2,264)		(3,208)		(5,471)
Total financing lease expense	1,238		401		1,717
Variable lease expense	890		—		890
Short-term lease expense (1)	3,058		5		3,109
Total lease expense for the period	$	31,260	$	698	$	32,134

(1) Includes expense of $2.7 million for the twelve months ended December 31, 2022 for rental of temporary cooling towers associated with the SJGS Unit 1 outage. These amounts are partially offset with insurance reimbursements of $2.7 million for the twelve months ended December 31, 2022.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Supplemental cash flow information related to the Company’s leases is as follows:


	Year Ended December 31, 2024						Year Ended December 31, 2023
	PNM		TNMP		TXNM Consolidated		PNM		TNMP		TXNM Consolidated
	(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	21,277	$	47	$	21,368	$	21,575	$	110	$	21,685
Operating cash flows from financing leases	206		102		340		183		73		256
Financing cash flows from financing leases	1,707		971		2,872		1,671		802		2,527

Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	101,594	$	100	$	102,261	$	138,204	$	6	$	138,210
Financing leases	4,962		3,715		9,850		6,421		5,407		11,828

Capitalized lease costs are reflected as investing activities on the Company’s Consolidated Statements of Cash Flows for the twelve months ended December 31, 2024 and 2023.

Future expected lease payments are shown below:


	As of December 31, 2024
	PNM						TNMP				TXNM Consolidated
			Operating										Operating
	Financing		Energy Storage		Other		Financing		Operating		Financing		Energy Storage		Other
	(In thousands)
2025	$	4,879	$	20,333	$	7,101	$	4,971	$	808	$	10,181	$	20,333	$	7,976
2026	4,300		20,333		7,042		3,635		90		8,258		20,333		7,201
2027	3,019		20,333		7,046		2,186		14		5,507		20,333		7,131
2028	1,640		20,333		7,049		811		11		2,571		20,333		7,133
2029	568		20,333		7,036		258		—		826		20,333		7,111
Later years	230		287,100		3,550		—		—		230		287,100		3,902
Total minimum lease payments	14,636		388,765		38,824		11,861		923		27,573		388,765		40,454
Less: Imputed interest	1,063		154,931		4,414		830		43		1,977		154,932		4,618
Lease liabilities	$	13,573	$	233,834	$	34,410	$	11,031	$	880	$	25,596	$	233,833	$	35,836

The above table includes $12.7 million, $10.4 million, and $23.3 million for PNM, TNMP, and TXNM at December 31, 2024 for expected future payments on fleet vehicle and equipment leases that could be avoided if the leased assets were returned and the lessor is able to recover estimated market value for the equipment from third parties.

At December 31, 2024, the Company has various lease arrangements that have been executed but have not yet commenced, which are primarily related to ESAs. The Company currently expects lease commencement dates in 2025 and 2029, with lease terms expiring in 2044 and 2045, and will recognize lease assets and liabilities upon lease commencement. The expected total fixed consideration to be paid for these arrangements, which includes non-lease payments, is approximately $226.3 million over the 20-year terms of the agreements.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

(9)Fair Value of Derivative and Other Financial Instruments

Fair value is defined as the price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. Fair value is based on current market quotes as available and is supplemented by modeling techniques and assumptions made by the Company to the extent quoted market prices or volatilities are not available. External pricing input availability varies based on commodity location, market liquidity, and term of the agreement. Valuations of derivative assets and liabilities take into account nonperformance risk, including the effect of counterparties’ and the Company’s credit risk. The Company regularly assesses the validity and availability of pricing data for its derivative transactions. Although the Company uses its best judgment in estimating the fair value of these instruments, there are inherent limitations in any estimation technique.

Energy Related Derivative Contracts

Overview

The primary objective for the use of commodity derivative instruments, including energy contracts, options, swaps, and futures, is to manage price risk associated with forecasted purchases of energy and fuel used to generate electricity, as well as managing anticipated generation capacity in excess of forecasted demand from existing customers. PNM’s energy related derivative contracts manage commodity risk. PNM is required to meet the demand and energy needs of its customers. PNM is exposed to market risk for the needs of its customers not covered under the FPPAC.

PNM has entered into agreements for the purchase and sale of power from third parties. In 2024, PNM entered into agreements to purchase a total of 125 MW from July 1, 2025 through August 31, 2025 in order to ensure that customer demand during the 2025 summer peak load period will be met. In addition, PNM entered into agreements to purchase a total of 150 MW from July 1, 2024 through July 31, 2024 and 100 MW from August 1, 2024 through August 30, 2024. These agreements are accounted for as derivative agreements and are considered economic hedges under the NMPRC approved hedging plan covered by its FPPAC.

Agreements for the purchase of 85 MW from June through September 2023 as well as agreements for the sale of 50 MW from September 1,2024 through December 31, 2024 were not considered derivatives because they qualified for a normal purchase, normal sale scope exception.

PNM’s operations are managed primarily through a net asset-backed strategy, whereby PNM’s aggregate net open forward contract position is covered by its forecasted excess generation capabilities or market purchases. PNM could be exposed to market risk if its generation capabilities were to be disrupted or if its load requirements were to be greater than anticipated. If all or a portion of load requirements were required to be covered as a result of such unexpected situations, commitments would have to be met through market purchases. TNMP does not enter into energy related derivative contracts.

Commodity Risk

Marketing and procurement of energy often involve market risks associated with managing energy commodities and establishing positions in the energy markets, primarily on a short-term basis. PNM routinely enters into various derivative instruments such as forward contracts, option agreements, and price basis swap agreements to economically hedge price and volume risk on power commitments and fuel requirements and to minimize the effect of market fluctuations. PNM monitors the market risk of its commodity contracts in accordance with approved risk and credit policies.

Accounting for Derivatives

Under derivative accounting and related rules for energy contracts, PNM accounts for its various instruments for the purchase and sale of energy, which meet the definition of a derivative, based on PNM’s intent. During the years ended December 31, 2024, 2023, and 2022, PNM was not hedging its exposure to the variability in future cash flows from commodity derivatives through designated cash flow hedges. The derivative contracts recorded at fair value that do not qualify or are not designated for cash flow hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power agreements, used to economically hedge generation assets, purchased power and fuel costs, and customer load requirements. Changes in the fair value of economic hedges are reflected in results of operations and are classified between operating revenues and cost of energy according to the intent of the hedge. PNM also uses such instruments under an NMPRC approved hedging plan to manage fuel and purchased power costs related to customers covered

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

by its FPPAC. Changes in the fair value of instruments covered by its FPPAC are recorded as regulatory assets and liabilities. PNM has no trading transactions.

Commodity Derivatives

PNM’s commodity derivative instruments that are recorded at fair value, all of which are accounted for as economic hedges and considered Level 2 fair value measurements, are presented in the following line items on the Consolidated Balance Sheets:


	Economic Hedges
	December 31,
	2024		2023
	(In thousands)
Other current assets	$	—	$	826


Other current liabilities	(5,737)		—


Net	$	(5,737)	$	826

Certain of PNM’s commodity derivative instruments in the above table are subject to master netting agreements whereby assets and liabilities could be offset in the settlement process. PNM does not offset fair value and cash collateral for derivative instruments under master netting arrangements and the above table reflects the gross amounts of fair value assets and liabilities for commodity derivatives.

As discussed above, PNM has NMPRC-approved guidelines for hedging arrangements to manage fuel and purchased power costs related to customers covered by its FPPAC. The table above includes zero in current assets and $5.7 million of current liabilities related to these arrangements at December 31, 2024 and $0.8 million in current assets and zero of current liabilities at December 31, 2023 with changes in fair value recorded as regulatory assets and regulatory liabilities. See Note 13.

At December 31, 2024 and 2023, PNM had no amounts recognized for the legal right to reclaim cash collateral. However, amounts posted as cash collateral under margin arrangements were $0.1 million at December 31, 2024 and $0.2 million at December 31, 2023. These amounts are included in other current assets on the Consolidated Balance Sheets. At December 31, 2024 and December 31, 2023, obligations to return cash collateral were zero and $0.2 million, which is included in other current liabilities on the Consolidated Balance Sheets.

The changes in the fair value of commodity derivative instruments that are considered economic hedges had no impact on PNM’s net earnings during the years ended December 31, 2024 and 2023. Commodity derivatives also had no impact on OCI for the periods presented. Commodity contract volume positions are presented in MMBTU for gas related contracts and in MWh for power related contracts. The table below presents PNM’s net buy (sell) volume positions:


	Economic Hedges
	MMBTU	MWh
December 31, 2024	—	89,900
December 31, 2023	—	(15,360)

PNM has contingent requirements to provide collateral under commodity contracts having an objectively determinable collateral provision that are in net liability positions and are not fully collateralized with cash. In connection with managing its commodity risks, PNM enters into master agreements with certain counterparties. If PNM is in a net liability position under an agreement, some agreements provide that the counterparties can request collateral if PNM’s credit rating is downgraded; other agreements provide that the counterparty may request collateral to provide it with “adequate assurance” that PNM will perform; and others have no provision for collateral.

The table below presents information about PNM’s contingent requirement to provide collateral under certain commodity contracts having an objectively determinable collateral position, that are in net liability positions, and that are not fully collateralized with cash. Contractual liability represents those commodity derivative contracts recorded at fair value on the balance sheet, determined on an individual contract basis without offsetting amounts for individual contracts that are in an asset position and could be offset under master netting agreements with the same counterparty. Cash collateral posted under these contracts does not reflect letters of credit under the Company’s revolving credit facilities that may have been issued as collateral. Net exposure is the net contractual liability for all contracts, including those designated as normal purchase and

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

normal sale, offset by existing collateral and by any offsets available under master netting agreements, including both assets and liability positions.


Contingent Feature - Credit Rating	Contractual Liability		Existing Cash Collateral		Net Exposure
	(In thousands)
December 31, 2024	$	5,737	$	—	$	5,737
December 31, 2023	$	—	$	—	$	—

Non-Derivative Financial Instruments

The carrying amounts reflected on the Consolidated Balance Sheets approximate fair value for cash, receivables, and payables due to the short period of maturity. Investment securities are carried at fair value. Investment securities consist of PNM assets held in the NDT for its share of decommissioning costs of PVNGS, a trust for PNM’s share of decommissioning costs at SJGS, and trusts for PNM’s share of final reclamation costs related to the coal mines serving SJGS and Four Corners. See Note 16. At December 31, 2024 and 2023, the fair value of investment securities included $384.6 million and $361.0 million for the NDT, $8.2 million and $12.3 million for the SJGS decommissioning trust, and $82.7 million and $71.1 million for the coal mine reclamation trusts.

PNM records a realized loss as an impairment for any available-for-sale debt security that has a fair value that is less than its carrying value. As a result, the Company has no available-for-sale debt securities for which carrying value exceeds fair value and there are no impairments considered to be “other than temporary” that are included in AOCI and not recognized in earnings. All gains and losses resulting from sales and changes in the fair value of equity securities are recognized immediately in earnings. Gains and losses recognized on the Consolidated Statements of Earnings related to investment securities in the NDT and reclamation trusts are presented in the following table:


	Year ended December 31,
	2024		2023		2022
	(In thousands)
Equity securities:
Net gains (losses) from equity securities sold	$	28,283	$	1,086	$	(6,940)
Net gains (losses) from equity securities still held	(10,071)		14,152		(38,025)
Total net gains (losses) on equity securities	18,212		15,238		(44,965)
Available-for-sale debt securities:


Net gains (losses) on debt securities	8,639		4,008		(33,392)
Net gains (losses) on investment securities	$	26,851	$	19,246	$	(78,357)

The proceeds and gross realized gains and losses on the disposition of securities held in the NDT and coal mine reclamation trusts are shown in the following table. Realized gains and losses are determined by specific identification of costs of securities sold. Gross realized losses shown below exclude the (increase)/decrease in realized impairment losses of $17.8 million, $19.1 million, and $(25.8) million for the years ended December 31, 2024, 2023 and 2022.


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Proceeds from sales	$	707,338	$	574,199	$	526,448
Gross realized gains	$	35,918	$	18,618	$	22,071
Gross realized (losses)	$	(16,814)	$	(32,649)	$	(36,623)

At December 31, 2024, the available-for-sale debt securities held by PNM, had the following final maturities:


	Fair Value
	(In thousands)
Within 1 year	$	24,446
After 1 year through 5 years	7,898




	$	32,344

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Fair Value Disclosures

The Company determines the fair values of its derivative and other financial instruments based on the hierarchy, which requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. There are three levels of inputs that may be used to measure fair value. Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date. Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly.

For investment securities, Level 2 fair values are provided by fund managers utilizing a pricing service. For Level 2 fair values, the pricing provider predominantly uses the market approach using bid side market values based upon a hierarchy of information for specific securities or securities with similar characteristics. Fair values of Level 2 investments in mutual funds are equal to net asset value (“NAV”). For commodity derivatives, Level 2 fair values are determined based on market observable inputs, which are validated using multiple broker quotes, including forward price, volatility, and interest rate curves to establish expectations of future prices. Credit valuation adjustments are made for estimated credit losses based on the overall exposure to each counterparty. For the Company’s long-term debt, Level 2 fair values are provided by an external pricing service. The pricing service primarily utilizes quoted prices for similar debt in active markets when determining fair value. Management of the Company independently verifies the information provided by pricing services. Uncategorized investments include common/collective investment trusts, which are measured at NAV at the end of each reporting period. Audited financial statements are received for each fund and reviewed by the Company annually. Fair value for these collective investment trusts is measured using a practical expedient provided under GAAP that allows the NAV per share to be used as fair value for investments in certain entities that do not have readily determinable fair values and are considered to be investment companies. Investments valued using this practical expedient are not required to be presented within the GAAP fair value hierarchy.

Items recorded at fair value by PNM on the Consolidated Balance Sheets are presented below by level of the fair value hierarchy along with gross unrealized gains on investments in available-for-sale debt securities.


			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Unrealized Gains
	(In thousands)
December 31, 2024
Cash and cash equivalents	$	150,745	$	150,745	$	—
Equity securities:
Corporate stocks, common	134,553		134,553		—

Mutual funds and other	135,779		135,779		—
Available-for-sale debt securities:
U.S. government	25,148		25,148		—		$	202

Municipals	—		—		—		—
Corporate and other	7,196		—		7,196		122
Investments categorized within the fair value hierarchy	$	453,421	$	446,225	$	7,196	$	324
Uncategorized Collective Investment Trust	22,103
Total investment securities	$	475,524

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022


			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Unrealized Gains
December 31, 2023	(In thousands)

Cash and cash equivalents	$	93,873	$	93,873	$	—
Equity securities:
Corporate stocks, common	77,422		77,422		—
Corporate stocks, preferred	4,323		504		3,819
Mutual funds and other	57,966		57,966		—
Available-for-sale debt securities:
U.S. government	35,113		34,522		591		$	2,055
International government	8,735		—		8,735		104
Municipals	53,436		—		53,436		2,872
Corporate and other	113,540		—		113,540		9,285
	$	444,408	$	264,287	$	180,121	$	14,316

The carrying amounts and fair values of long-term debt, all of which are considered Level 2 fair value measurements and are not recorded at fair value on the Consolidated Balance Sheets are presented below:


	Carrying Amount		Fair Value
December 31, 2024	(In thousands)
TXNM	$	4,923,368	$	4,706,076
PNM	$	2,459,592	$	2,284,362
TNMP	$	1,464,079	$	1,324,194

December 31, 2023
TXNM	$	4,521,811	$	4,260,509
PNM	$	2,261,780	$	2,107,588
TNMP	$	1,260,880	$	1,152,922

The carrying amount and fair value of the Company’s other investments presented on the Consolidated Balance Sheets are not material and not shown in the above table.

Investments Held by Employee Benefit Plans

As discussed in Note 11, PNM and TNMP have trusts that hold investment assets for their pension and other postretirement benefit plans. The fair value of the assets held by the trusts impacts the determination of the funded status of each plan, but the assets are not reflected on the Company’s Consolidated Balance Sheets. Both the PNM Pension Plan and the TNMP Pension Plan hold units of participation in the PNM Resources, Inc. Master Trust (the “PNMR Master Trust”), which was established for the investment of assets of the pension plans. The PNM Pension Plan’s investment allocation targets in 2024 consist of 35% equities, 15% alternative investments (both of which are considered return generating), and 50% fixed income. The TNMP Pension Plan’s investment allocation targets in 2024 consist of 16% equities, 14% alternative investments (both of which are considered return generating), and 70% fixed income.

GAAP provides a practical expedient that allows the net asset value per share to be used as fair value for investments in certain entities that do not have readily determinable fair values and are considered to be investment companies. Fair values for alternative investments held by the PNMR Master Trust and PNM OPEB Plan are valued using this practical expedient. Investments for which fair value is measured using that practical expedient are not required to be categorized within the fair value hierarchy. Level 2 fair values are provided by fund managers utilizing a pricing service. For level 2 fair values, the pricing provider predominately uses the market approach using bid side market value based upon a hierarchy of information for specific securities or securities with similar characteristics. Fair values of Level 2 investments in mutual funds are equal to net asset value as of year-end. Fair value prices for Level 2 corporate term loans predominately use the market approach which uses bid side market values based upon hierarchy information for specific securities or securities with similar characteristics.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Alternative investments include private equity funds, hedge funds, real estate funds, and a private collective investment trust. The private equity funds are not voluntarily redeemable. These investments are realized through periodic distributions occurring over a 10 to 15 years term after the initial investment. The real estate funds and hedge funds may be voluntarily redeemed but are subject to redemption provisions that may result in the funds not being redeemable in the near term. The private collective investment trust is a non-unitized fund that does not publish daily prices. Audited financial statements are received for each fund and are reviewed by the Company annually.

The valuation of alternative investments requires significant judgment by the pricing provider due to the absence of quoted market values, changes in market conditions, and the long-term nature of the assets. The significant unobservable inputs include estimates of liquidation value, current operating performance, and future expectations of performance.

The fair values of investments held by the employee benefit plans are as follows:


			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)
December 31, 2024	(In thousands)
PNM Pension Plan
Participation in PNMR Master Trust Investments:
Investments categorized within fair value hierarchy	$	319,528	$	106,220	$	213,308
Uncategorized investments	59,546
Total Master Trust Investments	$	379,074
TNMP Pension Plan
Participation in PNMR Master Trust Investments:
Investments categorized within fair value hierarchy	$	33,294	$	7,543	$	25,751
Uncategorized investments	4,872
Total Master Trust Investments	$	38,166




PNM OPEB Plan
Cash and cash equivalents	$	825	$	825	$	—
Equity securities:
Mutual funds	38,713		38,713		—
Investments categorized within fair value hierarchy	$	39,538	$	39,538	$	—
Uncategorized investments	31,176
	$	70,714
TNMP OPEB Plan
Cash and cash equivalents	$	111	$	111	$	—
Equity securities:
Mutual funds	6,987		6,987		—
Investments categorized within fair value hierarchy	$	7,098	$	7,098	$	—
Uncategorized investments	484
	$	7,582

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022


			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)
December 31, 2023	(In thousands)
PNM Pension Plan
Participation in PNMR Master Trust Investments:
Investments categorized within fair value hierarchy	$	342,296	$	136,474	$	205,822
Uncategorized investments	65,421
Total Master Trust Investments	$	407,717
TNMP Pension Plan
Participation in PNMR Master Trust Investments:
Investments categorized within fair value hierarchy	$	35,870	$	12,192	$	23,678
Uncategorized investments	5,258
Total Master Trust Investments	$	41,128
PNM OPEB Plan
Cash and cash equivalents	$	2,419	$	2,419	$	—
Equity securities:





Mutual funds	47,674		43,703		3,971
Investments categorized within fair value hierarchy	$	50,093	$	46,122	$	3,971
Uncategorized investments	23,290
Total Master Trust Investments	$	73,383
TNMP OPEB Plan
Cash and cash equivalents	$	162	$	162	$	—
Equity securities:





Mutual funds	8,241		7,806		435
Investments categorized within fair value hierarchy	$	8,403	$	7,968	$	435

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The fair values of investments in the PNMR Master Trust are as follows:


			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)
December 31, 2024	(In thousands)
PNMR Master Trust
Cash and cash equivalents	$	10,981	$	10,981	$	—
Equity securities:
Corporate stocks, common	34,418		34,418		—
Corporate stocks, preferred	—		—		—
Mutual funds and other	146,858		45,333		101,525
Fixed income securities:
U.S. government	56,303		23,031		33,272
International government	—		—		—
Municipals	4,718		—		4,718
Corporate and other	99,544		—		99,544
Total investments categorized within fair value hierarchy	352,822		$	113,763	$	239,059
Uncategorized investments:
Private equity funds	2,846
Hedge funds	34,126
Real estate funds	27,446
	$	417,240




December 31, 2023
PNMR Master Trust
Cash and cash equivalents	$	13,995	$	13,995	$	—
Equity securities:
Corporate stocks, common	27,167		27,167		—
Corporate stocks, preferred	741		741		—
Mutual funds and other	159,281		49,219		110,062
Fixed income securities:
U.S. government	61,684		57,544		4,140
International government	4,713		—		4,713
Municipals	5,071		—		5,071
Corporate and other	105,514		—		105,514
Total investments categorized within fair value hierarchy	378,166		$	148,666	$	229,500
Uncategorized investments:
Private equity funds	5,617
Hedge funds	35,137
Real estate funds	29,925
	$	448,845

(10)Variable Interest Entities

How an enterprise evaluates and accounts for its involvement with variable interest entities, focuses primarily on whether the enterprise has the power to direct the activities that most significantly impact the economic performance of a variable interest entity (“VIE”). This evaluation requires continual reassessment of the primary beneficiary of a VIE.

Valencia

PNM has a PPA to purchase all of the electric capacity and energy from Valencia, a 155 MW natural gas-fired power plant near Belen, New Mexico, through May 2028. A third party built, owns, and operates the facility while PNM is the sole purchaser of the electricity generated. PNM is obligated to pay fixed operation and maintenance and capacity charges in

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

addition to variable operation and maintenance charges under this PPA. For the years ended December 31, 2024, 2023, and 2022, PNM paid $20.5 million, $20.3 million, and $19.5 million for fixed charges and $2.4 million, $5.2 million, and $1.9 million for variable charges. PNM does not have any other financial obligations related to Valencia. The assets of Valencia can only be used to satisfy its obligations and creditors of Valencia do not have any recourse against PNM’s assets. During the term of the PPA, PNM has the option, under certain conditions, to purchase and own up to 50% of the plant or the VIE. The PPA specifies that the purchase price would be the greater of 50% of book value reduced by related indebtedness or 50% of fair market value.

PNM sources fuel for the plant, controls when the facility operates through its dispatch, and receives the entire output of the plant, which factors directly and significantly impact the economic performance of Valencia. Therefore, PNM has concluded that the third-party entity that owns Valencia is a VIE and that PNM is the primary beneficiary of the entity since PNM has the power to direct the activities that most significantly impact the economic performance of Valencia and will absorb the majority of the variability in the cash flows of the plant. As the primary beneficiary, PNM consolidates Valencia in its financial statements. Accordingly, the assets, liabilities, operating expenses, and cash flows of Valencia are included in the Consolidated Financial Statements of PNM although PNM has no legal ownership interest or voting control of the VIE. The assets and liabilities of Valencia are set forth below and are not shown separately on the Consolidated Balance Sheets. The owner’s equity and net income of Valencia are considered attributable to non-controlling interest.

Summarized financial information for Valencia is as follows:


Results of Operations
	Year Ended December 31
	2024		2023		2022
	(In thousands)
Operating revenues	$	22,763	$	25,421	$	21,403
Operating expenses	6,723		6,896		6,281
Other Misc (Income)/Expense	—		(8)		—
Earnings attributable to non-controlling interest	$	16,040	$	18,533	$	15,122


Financial Position
	December 31,
	2024		2023
	(In thousands)
Current assets	$	3,095	$	3,422
Net property, plant and equipment	44,411		47,253
Total assets	47,506		50,675
Current liabilities	606		717
Owners’ equity – non-controlling interest	$	46,900	$	49,958

Westmoreland San Juan Mining, LLC

As discussed in the subheading Coal Supply in Note 16, PNM and Westmoreland San Juan Mining, LLC (“WSJ LLC”), a subsidiary of Westmoreland Mining Holdings, LLC have an agreement under which mine reclamation services for SJGS will be provided.

TXNM issued $30.3 million in letters of credit to facilitate the issuance of reclamation bonds. The letters of credit support results in TXNM having a variable interest in WSJ LLC since TXNM is subject to possible loss in the event performance by TXNM is required under the letters of credit support. TXNM considers the possibility of loss under the letters of credit support to be remote since the purpose of posting the bonds is to provide assurance that WSJ LLC performs the required reclamation of the mine site in accordance with applicable regulations and the reclamation services agreement provides WSJ LLC the ability to recover the cost of reclamation. As discussed in Note 16, each of the SJGS participants has established and actively fund trusts to meet future reclamation obligations.

WSJ LLC is considered a VIE. TXNM’s analysis of its arrangements with WSJ LLC concluded that WSJ LLC has the ability to direct its reclamation services, which are the factors that most significantly impact the economic performance of WSJ LLC. Other than PNM being able to monitor reclamation activities, the reclamation services were solely under the control of WSJ LLC, including developing reclamation plans, hiring of personnel, and incurring operating and maintenance expenses.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Neither TXNM nor PNM has any ability to direct or influence the reclamation activities. PNM’s involvement through the reclamation services agreement is a protective right rather than a participating right and WSJ LLC still has the power to direct the activities that most significantly impact the economic performance of WSJ LLC. If WSJ LLC performs reclamation services more efficiently than anticipated, its economic performance will improve. Conversely, if WSJ LLC does not perform reclamation services as efficiently as anticipated, its economic performance will be negatively impacted. Accordingly, TXNM believes WSJ LLC is the primary beneficiary and, therefore, WSJ LLC is not consolidated by either TXNM or PNM. The amounts outstanding under the letters of credit support continue to be TXNM’s maximum exposure to loss from the VIE at December 31, 2024.

ETBC I

ETBC I is a wholly-owned, special purpose, subsidiary of PNM that was formed in August 2023 for the limited purpose of purchasing, owning, and administering energy transition property, issuing Securitized Bonds, and performing related activities authorized by the NMPRC. On November 15, 2023, ETBC I issued the ETBC I Securitized Bonds and used the proceeds to purchase energy transition property from PNM. The energy transition property purchased includes the right to impose, bill, collect, and adjust a non-bypassable energy transition charge from all PNM retail customers until the ETBC I Securitized Bonds are paid in full and all allowed financing costs have been recovered. The ETBC I Securitized bonds are secured by the energy transition property and cash collections from the energy transition charges are the sole source of funds to satisfy the debt obligation. The bondholders have no recourse to PNM.

PNM acts as the servicer of the energy transition property on behalf of ETBC I and is responsible for metering, calculating, billing, and collecting the Energy Transition Charges. On behalf of ETBC I, PNM is required to remit all collections of the Energy Transition Charges to the trustee for the ETBC I Securitized Bonds. PNM has the power to direct the activities that most significantly impact the economic performance of ETBC I and will absorb the majority of the variability in the cash flows of the entity. As the primary beneficiary, PNM consolidates ETBC I in its financial statements. Accordingly, the assets, liabilities, operating expenses, and cash flows of ETBC I are included in the Consolidated Financial Statements of PNM.

The following tables summarize the impact of ETBC I on PNM’s Consolidated Financial Statements:


	Results of Operations
	Year ended December 31,
	2024		2023
	(In thousands)
Electric Operating Revenues	$	24,798	$	2,914
Depreciation and amortization	4,550		407
Interest Charges	20,073		2,516
Other	175		(9)
Net Earnings	$	—	$	—



Financial Position
	December 31,
	2024		2023
	(In thousands)
Regulatory assets - Current	$	—	$	2,724
Restricted cash (included in Other current assets)	15,838		—
Restricted cash (included in Other deferred charges)	1,748		1,728
Securitized Cost (included in Regulatory assets - Deferred)	336,079		340,629
Current installments of long-term debt	6,907		2,529
Accrued interest and taxes	7,452		2,502
Regulatory liabilities - Current	6,975		—
Long-term Debt	331,726		338,521

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

(11)Pension and Other Postretirement Benefits

TXNM and its subsidiaries maintain qualified defined benefit pension plans, postretirement benefit plans providing medical and dental benefits, and executive retirement programs (collectively, the “PNM Plans” and “TNMP Plans”). TXNM maintains the legal obligation for the benefits owed to participants under these plans. The periodic costs or income of the PNM Plans and TNMP Plans are included in regulated rates to the extent attributable to regulated operations. PNM and TNMP receive a regulated return on the amounts funded for pension and OPEB plans in excess of the periodic cost or income to the extent included in retail rates (a “prepaid pension asset”).

Participants in the PNM Plans include eligible employees and retirees of TXNM and PNM. Participants in the TNMP Plans include eligible employees and retirees of TNMP. The PNM pension plan was frozen at the end of 1997 with regard to new participants, salary levels, and benefits. Through December 31, 2007, additional credited service could be accrued under the PNM pension plan up to a limit determined by age and service. The TNMP pension plan was frozen at December 31, 2005 with regard to new participants, salary levels, and benefits.

A plan sponsor is required to (a) recognize in its statement of financial position an asset for a plan’s overfunded status or a liability for a plan’s underfunded status; (b) measure a plan’s assets and its obligations that determine its funded status as of the end of the employer’s fiscal year; and (c) recognize changes in the funded status of a defined benefit postretirement plan in the year in which the changes occur.

Unrecognized prior service costs and unrecognized gains or losses are required to be recorded in AOCI and subsequently amortized. To the extent the amortization of these items will ultimately be recovered or returned through future rates, PNM and TNMP record the costs as a regulatory asset or regulatory liability. The amortization of these incurred costs is included as pension and postretirement benefit periodic cost or income in subsequent years.

The Company maintains trust funds for the pension and OPEB plans from which benefits are paid to eligible employees and retirees. The Company’s funding policy is to make contributions to the trusts, as determined by an independent actuary, that comply with minimum guidelines of the Employee Retirement Income Security Act and the IRC. Information concerning the fair value of investments is contained in Note 9. The Company has in place a policy that defines the investment objectives, establishes performance goals of asset managers, and provides procedures for the manner in which investments are to be reviewed. The plans implement investment strategies to achieve the following objectives:

•Implement investment strategies commensurate with the risk that the Corporate Investment Committee deems appropriate to meet the obligations of the pension plans and OPEB plans, minimize the volatility of expense, and account for contingencies

•Transition asset mix over the long-term to a higher proportion of high-quality fixed income investments as the plans’ funded statuses improve

Management is responsible for the determination of the asset target mix and the expected rate of return. The target asset allocations are determined based on consultations with external investment advisors. The expected long-term rate of return on pension and postretirement plan assets is calculated on the market-related value of assets. Actual gains and losses on pension and OPEB plan assets are recognized in the market-related value of assets equally over a period of not more than five years, which reduces year-to-year volatility. For the PNM Plans and TNMP Plans, the market-related value of assets is equal to the prior year’s market-related value of assets adjusted for contributions, benefit payments and investment gains and losses that are within a corridor of plus or minus 4.0% around the expected return on market value. Gains and losses that are outside the corridor are amortized over five years.

Pension Plans

For defined benefit pension plans, including the executive retirement plans, the PBO represents the actuarial present value of all benefits attributed by the pension benefit formula to employee service rendered prior to that date using assumptions regarding future compensation levels. The ABO represents the PBO without considering future compensation levels. Since the pension plans are frozen, the PBO and ABO are equal.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The following table presents information about the PBO, fair value of plan assets, and funded status of the plans:


	PNM				TNMP
	Year Ended December 31,				Year Ended December 31,
	2024		2023		2024		2023
	(In thousands)
PBO at beginning of year	$	418,657	$	433,645	$	42,582	$	43,961
Service cost	—		—		—		—
Interest cost	21,709		23,653		2,214		2,402

Actuarial (gain) loss	(6,063)		4,290		(2,047)		1,261
Benefits paid	(40,942)		(42,931)		(3,526)		(5,042)
Settlements	—		—		—		—
PBO at end of year	393,361		418,657		39,223		42,582
Fair value of plan assets at beginning of year	407,211		410,463		41,353		43,447
Actual return on plan assets	12,884		39,679		247		2,948
Employer contributions	1		—		151		—
Benefits paid	(40,942)		(42,931)		(3,526)		(5,042)
Settlements	—		—		—		—
Fair value of plan assets at end of year	379,154		407,211		38,225		41,353
Funded status – asset (liability) for pension benefits	$	(14,207)	$	(11,446)	$	(998)	$	(1,229)

Actuarial (gain) loss results from changes in:


	PNM				TNMP
	Year Ended December 31,				Year Ended December 31,
	2024		2023		2024		2023
	(in thousands)
Discount rates	$	(9,376)	$	8,806	$	(961)	$	969
Demographic experience	3,313		(1,777)		(1,125)		538
Mortality rate	—		(2,739)		—		(239)
Other assumptions and experience	—		—		39		(7)
	$	(6,063)	$	4,290	$	(2,047)	$	1,261

The following table presents pre-tax information about net actuarial (gain) loss in AOCI as of December 31, 2024.


	PNM		TNMP


	(In thousands)
Amounts in AOCI not yet recognized in net periodic benefit cost at beginning of year	$	104,067	$	—
Experience (gain) loss	12,081		456
Regulatory asset (liability) adjustment	(8,853)		(456)

Amortization recognized in net periodic benefit (income)	(4,782)		—
Amounts in AOCI not yet recognized in net periodic benefit cost at end of year	$	102,513	$	—

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The following table presents the components of net periodic benefit cost (income):


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
PNM
Service cost	$	—	$	—	$	—
Interest cost	21,709		23,653		16,857
Expected return on plan assets	(31,029)		(29,196)		(28,563)
Amortization of net loss	10,646		10,583		15,794
Amortization of prior service cost	—		—		—
Net periodic benefit cost	$	1,326	$	5,040	$	4,088
TNMP
Service cost	$	—	$	—	$	—
Interest cost	2,214		2,402		1,720
Expected return on plan assets	(2,749)		(2,697)		(2,472)
Amortization of net loss	556		439		932
Amortization of prior service cost	—		—		—
Settlement loss	—		—		1,033
Net periodic benefit cost	$	21	$	144	$	1,213

The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost (income). Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost (income) would be affected.


	Year Ended December 31,
PNM	2024		2023		2022
Discount rate for determining December 31 PBO	5.78	%	5.46	%	5.74	%
Discount rate for determining net periodic benefit cost	5.46		5.74		3.00
Expected return on plan assets	6.86		6.30		5.50
Rate of compensation increase	N/A		N/A		N/A
TNMP
Discount rate for determining December 31 PBO	5.78	%	5.47	%	5.75	%
Discount rate for determining net periodic benefit cost	5.47		5.75		3.01
Expected return on plan assets	5.95		5.50		4.40
Rate of compensation increase	N/A		N/A		N/A

The assumed discount rate for determining the PBO was determined based on a review of long-term high-grade bonds and management’s expectations. The expected long-term rate of return on plan assets reflects the average rate of earnings expected on the funds invested, or to be invested, to provide for the benefits included in the PBO. Factors that are considered include, but are not limited to, historic returns on plan assets, current market information on long-term returns (e.g., long-term bond rates) and current and target asset allocations between asset categories. If all other factors were to remain unchanged, a 1% decrease in the expected long-term rate of return would cause PNM’s and TNMP’s 2025 net periodic benefit cost to increase $4.1 million and $0.4 million (analogous changes would result from a 1% increase). The actual rate of return for the PNM and TNMP pension plans was 3.33% and 0.62% for the year ended December 31, 2024.

The Company’s long-term pension investment strategy is to invest in assets whose interest rate sensitivity is correlated with the pension liability. The Company uses an investment strategy, known as Liability Driven Investing, that increases the liability matching investments as the funded status of the pension plans improve. The Company’s investment allocation targets consist of 35% equities, 15% alternative investments (both of which are considered return generating), and 50% liability matching securities that are primarily bonds and other fixed income investments. Equity investments are primarily in domestic securities that include large-, mid-, and small-capitalization companies. The pension plans have a 13% targeted allocation to equities of companies domiciled primarily in developed countries outside of the U.S. The equity investments category includes active and passive managed domestic equity securities that are benchmarked against a variety of style indices. Fixed income investments are primarily corporate bonds of companies from diversified industries and government securities. Alternative investments include investments in hedge funds, real estate funds, and private equity funds. The private equity funds are structured as multi-manager multi-strategy fund of funds to achieve a diversified position in these asset classes. The hedge

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

funds use multi-strategies that pursue various absolute return strategies such as relative value, merger arbitrage, event driven equities, and structured credit. The real estate investments are commingled real estate portfolios that invest in a diversified portfolio of assets including commercial property, infrastructure, storage facilities and multi-family housing. See Note 9 for fair value information concerning assets held by the pension plans.

The following pension benefit payments are expected to be paid:


	PNM		TNMP
	(In thousands)
2025	$	40,927	$	4,239
2026	39,585		4,188
2027	38,706		4,000
2028	37,373		3,902
2029	36,231		3,759
2030 - 2034	160,876		15,464

Based on current law, funding requirements, and estimates of portfolio performance, the Company does not expect to make any cash contributions to the pension plans in 2025 through 2028. PNM does expect to make a cash contribution of $7.9 million in 2029. TNMP does not expect to make any cash contributions to the pension plans from 2025 through 2029. The funding assumptions were developed using a discount rate of 5.35%. Actual amounts to be funded in the future will be dependent on the actuarial assumptions at that time, including the appropriate discount rates. PNM and TNMP may make additional contributions at their discretion.

Other Postretirement Benefit Plans

For postretirement benefit plans, the APBO is the actuarial present value of all future benefits attributed under the terms of the postretirement benefit plan to employee service rendered to date. The following table presents information about the APBO, the fair value of plan assets, and the funded status of the plans:


	PNM				TNMP
	Year Ended December 31,				Year Ended December 31,
	2024		2023		2024		2023
	(In thousands)
APBO at beginning of year	$	46,217	$	49,950	$	7,331	$	7,705
Service cost	—		—		21		21
Interest cost	2,387		2,703		385		425
Participant contributions	1,463		1,592		357		359
Actuarial (gain)	(2,205)		(1,608)		(147)		(282)
Benefits paid	(6,261)		(6,420)		(1,193)		(897)
Curtailment loss	—		—		—		—

APBO at end of year	41,601		46,217		6,754		7,331
Fair value of plan assets at beginning of year	73,392		70,301		8,353		8,718
Actual return on plan assets	3,216		7,762		25		173
Employer contributions	193		157		—		—
Participant contributions	1,463		1,592		357		359
Benefits paid	(6,261)		(6,420)		(1,193)		(897)
Fair value of plan assets at end of year	72,003		73,392		7,542		8,353
Funded status – asset	$	30,402	$	27,175	$	788	$	1,022

As of December 31, 2024, the fair value of plan assets exceeds the APBO for both PNM’s and TNMP’s OPEB Plans, and the resulting net asset is presented in other deferred charges on the Consolidated Balance Sheets.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Actuarial (gain) loss results from changes in:


	PNM				TNMP
	Year Ended December 31,				Year Ended December 31,
	2024		2023		2024		2023
	(in thousands)
Discount rates	$	(877)	$	868	$	(179)	$	174
Claims, contributions, and demographic experience	(1,425)		(2,171)		32		(423)
Assumed participation rate	97		—		—		—
Mortality rate	—		(305)		—		(33)

Dental trend assumption	—		—		—		—
	$	(2,205)	$	(1,608)	$	(147)	$	(282)

In the year ended December 31, 2024, actuarial losses of $0.1 million were recorded as adjustments to regulatory assets for the PNM OPEB plan. For the TNMP OPEB plan, actuarial losses of $0.3 million were recorded as adjustments to regulatory liabilities.

The following table presents the components of net periodic benefit cost (income):


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
PNM
Service cost	$	—	$	—	$	10
Interest cost	2,387		2,703		1,914
Expected return on plan assets	(5,563)		(4,969)		(4,351)
Amortization of net loss	—		—		—

Curtailment loss	—		—		836
Net periodic benefit (income)	$	(3,176)	$	(2,266)	$	(1,591)
TNMP
Service cost	$	21	$	21	$	38
Interest cost	385		425		307
Expected return on plan assets	(515)		(481)		(418)
Amortization of net (gain)	(642)		(760)		(520)

Net periodic benefit (income)	$	(751)	$	(795)	$	(593)

The following significant weighted-average assumptions were used to determine the APBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the APBO and net periodic benefit cost would be affected.


	Year Ended December 31,
PNM	2024		2023		2022
Discount rate for determining December 31 APBO	5.78	%	5.48	%	5.75	%
Discount rate for determining net periodic benefit cost	5.48		5.75		2.99
Expected return on plan assets	6.60		5.90		4.75
Rate of compensation increase	N/A		N/A		N/A
TNMP
Discount rate for determining December 31 APBO	5.78	%	5.48	%	5.75	%
Discount rate for determining net periodic benefit cost	5.48		5.75		2.99
Expected return on plan assets	5.25		4.70		3.80
Rate of compensation increase	N/A		N/A		N/A

The assumed discount rate for determining the APBO was determined based on a review of long-term high-grade bonds and management’s expectations. The expected long-term rate of return on plan assets reflects the average rate of earnings expected on the funds invested, or to be invested, to provide for the benefits included in the APBO. Factors that are considered include, but are not limited to, historic returns on plan assets, current market information on long-term returns (e.g., long-term bond rates), and current and target asset allocations between asset categories. If all other factors were to remain unchanged, a

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

1% decrease in the expected long-term rate of return would cause PNM’s and TNMP’s 2025 net periodic benefit cost to increase $0.8 million and $0.1 million (analogous changes would result from a 1% increase). The actual rate of return for the PNM and TNMP OPEB plans was 4.5% and 0.3% for the year ended December 31, 2024.

The following table shows the assumed health care cost trend rates for the PNM OPEB plan:


	PNM
	December 31,
	2024		2023
Health care cost trend rate assumed for next year	6.50	%	6.00	%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	4.75		4.75
Year that the rate reaches the ultimate trend rate	2033		2029

TNMP’s exposure to cost increases in the OPEB plan is minimized by a provision that limits TNMP’s share of costs under the plan. Costs of the plan in excess of the limit, which was reached at the end of 2001, are wholly borne by the participants. As a result, a one-percentage-point change in assumed health care cost trend rates would have no effect on either the net periodic expense or the year-end APBO. Effective January 1, 2018, the PNM OPEB plan was amended to limit the annual increase in the Company’s costs to 5%. Increases in excess of the limit are born by the PNM OPEB plan participants.

The Company’s OPEB plans invest in a portfolio that is diversified by asset class and style strategies. The OPEB plans generally use the same pension fixed income and equity investment managers and utilize the same overall investment strategy as described above for the pension plans, except there is no allocation to alternative investments. The OPEB plans have a target asset allocation of 30% equities and 70% fixed income. See Note 9 for fair value information concerning assets held by the other postretirement benefit plans. The following OPEB payments, which reflect expected future service and are net of participant contributions, are expected to be paid:


	PNM		TNMP
	(In thousands)
2025	$	4,771	$	589
2026	4,560		597
2027	4,333		588
2028	4,128		585
2029	3,871		574
2030 - 2034	16,604		2,606

PNM and TNMP made cash contributions to the OPEB trusts in 2024 of less than $0.1 million and $0.2 million and did not make any cash contributions in 2023. PNM and TNMP do not expect to make cash contributions to the OPEB trusts in 2025-2029. However, a portion of the disbursements attributable to the OPEB trust are paid by PNM and are therefore considered to be contributions to the PNM OPEB plan. Payments by PNM on behalf of the PNM OPEB plan are expected to be $2.0 million in 2025 and $11.1 million in 2026-2029.

Executive Retirement Programs

For the executive retirement programs, the following table presents information about the PBO and funded status of the plans:


	PNM				TNMP
	Year Ended December 31,				Year Ended December 31,
	2024		2023		2024		2023
	(In thousands)
PBO at beginning of year	$	9,714	$	10,042	$	316	$	344
Service cost	—		—		—		—
Interest cost	496		540		15		18
Actuarial (gain) loss	(47)		411		(314)		13
Benefits paid	(1,132)		(1,279)		(17)		(59)
PBO at end of year – funded status	9,031		9,714		—		316
Less current liability	1,171		1,210		—		64
Non-current liability	$	7,860	$	8,504	$	—	$	252

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The following table presents pre-tax information about net actuarial loss in AOCI as of December 31, 2024.


	December 31, 2024
	PNM		TNMP
	(In thousands)
Amount in AOCI not yet recognized in net periodic benefit cost at beginning of year	$	1,104	$	—
Experience (gain)	(45)		(314)
Regulatory asset adjustment	26		314
Amortization recognized in net periodic benefit (income)	(84)		—
Amount in AOCI not yet recognized in net periodic benefit cost at end of year	$	1,001	$	—

The following table presents the components of net periodic benefit cost:


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
PNM
Service cost	$	—	$	—	$	—
Interest cost	496		540		362
Amortization of net loss	200		152		327
Amortization of prior service cost	—		—		—
Net periodic benefit cost	$	696	$	692	$	689
TNMP
Service cost	$	—	$	—	$	—
Interest cost	15		18		11
Amortization of net loss	—		—		—
Amortization of prior service cost	—		—		—
Net periodic benefit cost	$	15	$	18	$	11

The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost would be affected.


	Year Ended December 31,
PNM	2024		2023		2022
Discount rate for determining December 31 PBO	5.78	%	5.45	%	5.73	%
Discount rate for determining net periodic benefit cost	5.45		5.73		3.02
Long-term rate of return on plan assets	N/A		N/A		N/A
Rate of compensation increase	N/A		N/A		N/A
TNMP
Discount rate for determining December 31 PBO	N/A		5.47	%	5.75	%
Discount rate for determining net periodic benefit cost	5.47		5.75		3.01
Long-term rate of return on plan assets	N/A		N/A		N/A
Rate of compensation increase	N/A		N/A		N/A

The assumed discount rate for determining the PBO was determined based on a review of long-term high-grade bonds and management’s expectations. The impacts of changes in assumptions or experience were not significant.

Disbursements under the executive retirement program, funded by PNM and TNMP, which are considered to be contributions to the plan were $1.3 million and less than $0.1 million in the year ended December 31, 2024 and $1.3 million and $0.1 million for the year ended December 31, 2023.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The following executive retirement plan payments, which reflect expected future service, are expected:


	PNM		TNMP
	(In thousands)
2025	$	1,205	$	—
2026	1,150		—
2027	1,089		—
2028	1,022		—
2029	952		—
2030 - 2034	3,699		—

Other Retirement Plans

TXNM sponsors a 401(k) defined contribution plan for eligible employees, including those of its subsidiaries. TXNM’s contributions to the 401(k) plan consist of a discretionary matching contribution equal to 75% of the first 6% of eligible compensation contributed by the employee on a before-tax basis. TXNM also makes a non-matching contribution ranging from 3% to 10% of eligible compensation based on the eligible employee’s age. TXNM also provides executive deferred compensation benefits through an unfunded, non-qualified plan. The purpose of this plan is to permit certain key employees of TXNM who participate in the 401(k) defined contribution plan to defer compensation and receive credits without reference to the certain limitations on contributions.

A summary of expenses for these other retirement plans is as follows:


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
TXNM
401(k) plan	$	17,514	$	16,118	$	15,844
Non-qualified plan	$	4,350	$	1,197	$	(1,027)
PNM
401(k) plan	$	11,896	$	10,839	$	11,067
Non-qualified plan	$	2,937	$	825	$	(721)
TNMP
401(k) plan	$	5,617	$	5,279	$	4,776
Non-qualified plan	$	1,414	$	372	$	(305)

(12)Stock-Based Compensation

TXNM has various stock-based compensation programs, which provide restricted stock awards, that are performance based and time based, under the Performance Equity Plan (“PEP”). Although certain PNM and TNMP employees are eligible to participate in the TXNM plans, PNM and TNMP do not have separate employee stock-based compensation plans. Performance stock awards awarded under the PEP are awarded for a three-year, overlapping performance period. Performance stock awards with performance periods ending before 2024 or after 2025 are subject to achieving both performance and market targets. Performance stock awards with performance periods ending from 2024 through 2025 do not include market targets. Other awards of restricted stock are only subject to time-based vesting requirements.

Performance Equity Plan

The PEP provides for the granting of non-qualified stock options, restricted stock rights, performance shares, performance units, and stock appreciation rights to officers, key employees, and non-employee members of the Board. Restricted stock under the PEP refers to awards of stock subject to vesting, performance, or market conditions rather than to shares with contractual post-vesting restrictions. Generally, the awards vest ratably over three years from the grant date of the award. However, awards with performance or market conditions vest upon satisfaction of those conditions. In addition, plan provisions provide that upon retirement, participants become 100% vested in certain stock awards. The vesting period for awards of restricted stock to non-employee members of the Board is one year. The total number of shares of TXNM common stock subject to all awards under the 2014 PEP, as approved by TXNM’s shareholders in May 2014, may not exceed 13.5 million shares, subject to adjustment and certain share counting rules set forth in the PEP. This share pool is charged five

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

shares for each share subject to restricted stock or other full value award. In May 2023, TXNM’s shareholders approved the 2023 PEP which set the maximum number of shares subject to all awards to be 2.5 million shares. The 2023 PEP share pool is charged a single share for each award.

Source of Shares

The source of shares for exercised stock options and vested restricted stock is currently shares acquired on the open market by an independent agent, rather than newly issued shares.

Accounting for Stock Awards

The stock-based compensation expense related to restricted stock awards without performance or market conditions to participants that are retirement eligible on the grant date is recognized immediately at the grant date and is not amortized. Compensation expense for other such awards is amortized to compensation expense over the shorter of the requisite vesting period or the period until the participant becomes retirement eligible. Compensation expense for performance-based shares is recognized ratably over the performance period as required service is provided and is adjusted periodically to reflect the level of achievement expected to be attained. Compensation expense related to market-based shares is recognized ratably over the measurement period, regardless of the actual level of achievement, provided the employees meet their service requirements.

Total compensation expense for stock-based payment arrangements recognized by TXNM for the years ended December 31, 2024, 2023, and 2022 was $9.5 million, $7.2 million, and $7.9 million. Stock compensation expense of $5.0 million, $4.8 million, and $5.3 million was charged to PNM and $2.7 million, $2.4 million, and $2.6 million was charged to TNMP. At December 31, 2024, TXNM had unrecognized compensation expense related to stock awards of $5.0 million, which is expected to be recognized over an average of 2.26 years.

TXNM receives a tax deduction for the value of restricted stock at the vesting date. To the extent the tax deduction exceeds the Company’s cumulative expense related to a stock award, an excess tax benefit is recorded. When the cumulative expense exceeds the tax deduction, a tax deficiency is recorded. All excess tax benefits and deficiencies are recorded to tax expense and classified as operating cash flows when used to reduce taxes payable.


	Year Ended December 31,
Excess Tax Benefits (Deficiencies)	2024		2023		2022
	(In thousands)
PNM	$	10	$	185	$	(65)
TNMP	4		76		(26)
TXNM	17		261		(91)

TNMP used excess tax benefits to reduce income taxes payable and the benefit was reflected in cash flows from operating activities. The benefit of excess tax benefits at PNM and TXNM will be reflected in operating cash flows when they reduce income taxes payable.

The grant date fair value for restricted stock and stock awards with Company internal performance targets is determined based on the market price of TXNM common stock on the date of the agreements reduced by the present value of future dividends that will not be received prior to vesting. The grant date fair value is applied to the total number of shares that are anticipated to vest, although the number of performance shares that ultimately vest cannot be determined until after the performance periods end. The grant date fair value of stock awards with market targets is determined using Monte Carlo simulation models, which provide grant date fair values that include an expectation of the number of shares to vest at the end of the measurement period.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The following table summarizes the weighted-average assumptions used to determine the awards grant date fair value:


	Year Ended December 31,
Restricted Shares and Performance-Based Shares	2024			2023			2022
Expected quarterly dividends per share	$	0.3875		$	0.3675		$	0.3475
Risk-free interest rate	4.27		%	4.46		%	1.46		%

Market-Based Shares (1)
Dividend yield	4.21		%	N/A			N/A
Expected volatility	13.09		%	N/A			N/A
Risk-free interest rate	4.31		%	N/A			N/A

(1) Restricted stock expected to be awarded under the PEP for performance periods ending in 2022 and 2023 do not have market targets.

The following table summarizes activity in restricted stock awards including performance-based and market-based shares:


	Restricted Stock
	Shares	Weighted-Average Grant Date Fair Value
Outstanding at December 31, 2023	212,080	$	40.33
Granted	249,282	33.51
Released	(218,403)	38.37
Forfeited	(1,722)	43.80

Outstanding at December 31, 2024	241,237	$	37.05

Included as granted and released in the table above are 80,492 previously awarded shares that were earned for the 2021 - 2023 performance measurement period and ratified by the Board in February 2024 (based upon achieving targets at above “target”, below “maximum” levels). Also included, as granted and released, are 8,791 of other RSAs for participants who retired and immediately vested plus a one-time sign-on RSA that immediately vested (discussed below). Excluded from the above table are 49,489 previously awarded shares that were earned for the 2022 - 2024 performance measurement period and ratified by the Board in February 2025 (based upon achieving targets at above “threshold”, below “target” levels). Also excluded from the table above are 150,976 and 227,472 shares for the three-year performance periods ending in 2025 and 2026 that will be awarded if all performance criteria are achieved at maximum levels and all executives remain eligible.

On December 4, 2023, the Company entered into retention agreements with its Chairman and Chief Executive Officer and its Senior Vice President and General Counsel under which they would be awarded a total of 26,766 and 8,922 respectively of restricted stock rights if they remained employed through the award’s vesting date which is the earliest of 24 months from the grant date, the closing of the Merger, or six months following the termination of the Merger. As of December 31, 2023, upon the notice from Avangrid regarding the termination of the Merger Agreement, these awards vested on June 30, 2024.

On December 4, 2023, the Company entered into a retention agreement with its President and Chief Operating Officer under which he would receive a retention bonus of $1.0 million to be paid in increments beginning in December 2023 and continuing each December until 2025. On April 8, 2024, pursuant to the retention agreement, the Board elected to convert the unvested portion of the retention bonus of $0.8 million into restricted stock rights whereby each share of restricted stock is equal to one share of Company common stock as of the first trading day after expiration of the then current black-out period. On May 3, 2024, subsequent to the expiration of the black-out period, 19,851 restricted stock rights were awarded and 6,617 have vested as of December 31, 2024, in accordance with the original terms of the retention agreement.

On September 16, 2024, in connection with a one-time sign-on equity grant, the Company’s newly appointed General Counsel, Senior Vice President Regulatory and Public Policy, and Corporate Secretary was awarded 9,300 shares of restricted stock, of which 50% vested immediately and the remaining 50% will vest on the first anniversary of his start date, subject to continued employment through the vesting date.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The following table provides additional information concerning restricted stock activity, including performance-based and market-based shares:


	Year Ended December 31,
Restricted Stock	2024		2023		2022
Weighted-average grant date fair value	$	38.37	$	41.98	$	41.04
Total fair value of restricted shares that vested (in thousands)	$	8,380	$	8,689	$	7,368

(13) Regulatory Assets and Liabilities

The operations of PNM and TNMP are regulated by the NMPRC, PUCT, and FERC and the provisions of GAAP for rate-regulated enterprises are applied to its regulated operations. Regulatory assets represent probable future recovery of previously incurred costs that will be collected from customers through the ratemaking process. Regulatory liabilities represent probable future reductions in revenues associated with amounts that are to be credited to customers through the ratemaking process. Regulatory assets and liabilities reflected in the Consolidated Balance Sheets are presented below.


	PNM				TNMP
	December 31,				December 31,
	2024		2023		2024		2023
Assets:	(In thousands)
Current:
FPPAC	$	30,487	$	65,251	$	—	$	—
NMPRC Hedging Plan	5,737		—		—		—
Transmission cost recovery factor	—		—		5,268		—
Energy efficiency costs	—		—		—		50
Renewable energy rider	—		5,021		—		—
SJGS Energy Transition Property	—		2,724		—		—
	36,224		72,996		5,268		50






Non-Current:
SJGS Energy Transition Property	$	336,079	$	340,629	$	—	$	—
SJGS ETA	24,996		—		—		—
SJGS - non-ETA	114,333		122,246		—		—
PVNGS leased interest	82,982		80,777		—		—

EIM	15,189		18,731		—		—
TEP	4,942		2,644		—		—
Loss on reacquired debt	12,507		13,806		23,721		25,019
Pension and OPEB	176,171		172,508		21,087		21,854
Deferred income taxes	74,925		71,359		8,570		8,882

Excess ADIT	—		—		6,542		—
AMS retirement and other costs	—		—		12,851		12,343
Deferred COVID-19 costs	3,328		5,664		—		—
Hurricane Beryl	—		—		20,958		—
Other	11,858		10,363		10,964		7,556
	857,310		838,727		104,693		75,654
Total regulatory assets	$	893,534	$	911,723	$	109,961	$	75,704

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022



	PNM				TNMP
	December 31,				December 31,
	2024		2023		2024		2023



Liabilities:	(In thousands)
Current:

SJGS rate refunds	$	(157)	$	(113,372)	$	—	$	—
PVNGS rate refunds	(19,194)		(19,194)		—		—
Renewable energy rider	(4,786)		—		—		—
Energy efficiency costs	(2,459)		(1,454)		(602)		—
Transmission Cost Recovery Factor	—		—		—		(5,159)
SJGS Energy Transition Property	(6,975)		—
NMPRC hedging plan	—		(826)		—		—
	(33,571)		(134,846)		(602)		(5,159)
Non-Current:
Cost of removal	$	(247,280)	$	(247,627)	$	(147,296)	$	(117,759)
Deferred income taxes	(253,158)		(281,588)		(80,152)		(83,459)

Renewable energy tax benefits	(13,317)		(14,463)		—		—



PVNGS rate refunds	(3,277)		(19,194)		—		—
Pension and OPEB	—		—		(2,589)		(3,644)
COVID-19 cost savings	(469)		(900)		—		—
Other	(1,200)		(1,249)		—		(1,434)
	(518,701)		(565,021)		(230,037)		(206,296)
Total regulatory liabilities	$	(552,272)	$	(699,867)	$	(230,639)	$	(211,455)

The Company’s regulatory assets and regulatory liabilities are reflected in rates charged to customers or have been addressed in a regulatory proceeding. The Company does not receive or pay a rate of return on the following regulatory assets and regulatory liabilities (and their remaining amortization periods): SJGS Energy Transition Property (over the life of the ETBC I Securitized Bonds); portions of PVNGS Leased Interest (through 2044); SJGS rate refunds (through 2024); PVNGS rate refunds (through 2025); deferred income taxes (over the remaining life of the taxable item, up to the remaining life of utility plant); pension and OPEB costs (through 2040).

The Company is permitted, under rate regulation, to accrue and record a regulatory liability for the estimated cost of removal and salvage associated with certain of its assets through depreciation expense. Actuarial losses and prior service costs for pension plans are required to be recorded in AOCI; however, to the extent authorized for recovery through the regulatory process these amounts are recorded as regulatory assets or liabilities. Based on prior regulatory approvals, the amortization of these amounts will be included in the Company’s rates. Based on a current evaluation of the various factors and conditions that are expected to impact future cost recovery, the Company believes that future recovery of its regulatory assets is probable.

(14)Construction Program and Jointly-Owned Electric Generating Plants

PNM is a participant in jointly-owned power plant projects. The participation agreement for SJGS expired on September 30, 2022. The primary operating or participation agreements for the other joint projects expire in July 2041 for Four Corners, December 2046 for Luna, and November 2047 for PVNGS.

PNM’s expenditures for additions to utility plant were $682.4 million in 2024, including expenditures on jointly-owned projects. TNMP does not participate in the ownership or operation of any generating plants, but incurred expenditures for additions to utility plant of $541.6 million during 2024. On a consolidated basis, TXNM’s expenditures for additions to utility plant were $1,247.0 million in 2024.

Joint Projects

Under the agreements for the jointly-owned projects, PNM has an undivided interest in each asset and liability of the project and records its pro-rata share of each item in the corresponding asset and liability account on PNM’s Consolidated Balance Sheets. Likewise, PNM records its pro-rata share of each item of operating and maintenance expenses for its jointly-owned plants within the corresponding operating expense account in its Consolidated Statements of Earnings. PNM is responsible for financing its share of the capital and operating costs of the joint projects.

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

At December 31, 2024, PNM’s interests and investments in jointly-owned generating facilities are:


Station (Type)	Plant in Service		Accumulated Depreciation (1)		Construction Work in Progress		Composite Interest
	(In thousands)
PVNGS (Nuclear)	$	800,999	$	415,747	$	32,650	7.29	%
Four Corners Units 4 and 5 (Coal)	$	291,355	$	98,049	$	14,579	13.00	%
Luna (Gas)	$	99,479	$	37,448	$	2,658	33.33	%

(1) Includes cost of removal.

Palo Verde Nuclear Generating Station

PNM is a participant in the three units of PVNGS with APS (the operating agent), SRP, EPE, SCE, SCPPA, and The Department of Water and Power of the City of Los Angeles. PNM has ownership interests of 2.3% in Unit 1, 9.4% in Unit 2, and 10.2% in Unit 3. PNM previously had a 10.2% undivided interest in PVNGS, with portions of its interests in Units 1 and 2 held under leases. In January 2023, leased capacity of 104 MW in PVNGS Unit 1 expired and the rights to the capacity were acquired by SRP from the lessors subsequently, reducing PNM’s interest in PVNGS to 7.6% at December 31, 2023. In January 2024, the leased capacity of 10 MW in PVNGS Unit 2 expired and the rights were also acquired by SRP, further reducing PNM’s interest in PVNGS to 7.3%. See Note 8 for additional information concerning the PVNGS leases.

Four Corners Power Plant

PNM is a participant in two units of Four Corners with APS (the operating agent), an affiliate of APS, SRP, and Tucson. PNM has a 13.0% undivided interest in Units 4 and 5 of Four Corners. The Four Corners plant site is located on land within the Navajo Nation and is subject to an easement from the federal government. APS, on behalf of the Four Corners participants, negotiated amendments to an existing agreement with the Navajo Nation, which extends the owners’ right to operate the plant on the site to July 2041. See Notes 16 and 17 for additional information about Four Corners.

Luna Energy Facility

Luna is a combined-cycle power plant near Deming, New Mexico. Luna is owned equally by PNM, Tucson, and Samchully Power & Utilities 1, LLC. The operation and maintenance of the facility has been contracted to North American Energy Services by PNM.

(15)Asset Retirement Obligations

AROs are recorded based on studies to estimate the amount and timing of future ARO expenditures and reflect underlying assumptions, such as discount rates, estimates of the future costs for decommissioning, and the timing of the removal activities to be performed. Approximately 75.7% of PNM’s total ARO liabilities are related to nuclear decommissioning of PVNGS. PNM is responsible for all decommissioning obligations related to its entire interest in PVNGS, including portions both during and after termination of the leases. Studies of the decommissioning costs of PVNGS, SJGS, Four Corners, and other facilities are performed periodically and revisions to the ARO liabilities are recorded. Changes in the assumptions underlying the calculations may also require revisions to the estimated AROs when identified.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

A reconciliation of the ARO liabilities is as follows:


	TXNM		PNM		TNMP
	(In thousands)
Liability at December 31, 2021	$	234,146	$	233,383	$	763
Liabilities incurred	—		—		—
Liabilities settled	—		—		—
Accretion expense	10,767		10,702		65
Revisions to estimated cash flows(1)	(21,536)		(21,536)		—
Liability at December 31, 2022	223,377		222,549		828
Liabilities incurred	—		—		—
Liabilities settled	(3,482)		(3,482)		—
Accretion expense	10,218		10,148		70
Revisions to estimated cash flows(2)	15,418		15,418		—
Liability at December 31, 2023	245,531		244,633		898
Liabilities incurred	—		—		—
Liabilities settled	(12,451)		(12,432)		(19)
Accretion expense	11,538		11,462		76
Revisions to estimated cash flows	—		—		—
Liability at December 31, 2024	$	244,618	$	243,663	$	955

(1) Reflects a decrease of $21.5 million related to an updated SJGS decommissioning study.

(2) Reflects an increase of $15.4 million related to an updated PVNGS decommissioning study.

(16)Commitments and Contingencies

Overview

There are various claims and lawsuits pending against the Company. In addition, the Company is subject to federal, state, and local environmental laws and regulations and periodically participates in the investigation and remediation of various sites. In addition, the Company periodically enters into financial commitments in connection with its business operations. Also, the Company is involved in various legal and regulatory proceedings in the normal course of its business. See Note 17. It is not possible at this time for the Company to determine fully the effect of all litigation and other legal and regulatory proceedings on its financial position, results of operations, or cash flows.

With respect to some of the items listed below, the Company has determined that a loss is not probable or that, to the extent probable, cannot be reasonably estimated. In some cases, the Company is not able to predict with any degree of certainty the range of possible loss that could be incurred. The Company assesses legal and regulatory matters based on current information and makes judgments concerning their potential outcome, giving due consideration to the nature of the claim, the amount and nature of any damages sought, and the probability of success. Such judgments are made with the understanding that the outcome of any litigation, investigation, or other legal proceeding is inherently uncertain. The Company records liabilities for matters where it is probable a loss has been incurred and the amount of loss is reasonably estimatable. The actual outcomes of the items listed below could ultimately differ from the judgments made and the differences could be material. The Company cannot make any assurances that the amount of reserves or potential insurance coverage will be sufficient to cover the cash obligations that might be incurred as a result of litigation or regulatory proceedings. Except as otherwise disclosed, the Company does not expect that any known lawsuits, environmental costs, or commitments will have a material effect on its financial condition, results of operations, or cash flows.

Commitments and Contingencies Related to the Environment

PVNGS Decommissioning Funding

The costs of decommissioning a nuclear power plant are substantial. PNM is responsible for all decommissioning obligations related to its entire interest in PVNGS, including portions under leases both during and after termination of the leases. PNM has a program for funding its share of decommissioning costs for PVNGS, including portions previously held under leases. The nuclear decommissioning funding program is invested in equities and fixed income instruments in qualified and non-qualified trusts. PNM funded $1.3 million for each of the years ended December 31, 2024, 2023 and 2022 into the qualified trust funds. The fair value of the trusts at December 31, 2024 and 2023 was $384.6 and $361.0 million.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Nuclear Spent Fuel and Waste Disposal

Nuclear power plant operators are required to enter into spent fuel disposal contracts with the DOE that require the DOE to accept and dispose of all spent nuclear fuel and other high-level radioactive wastes generated by domestic power reactors. Although the Nuclear Waste Policy Act required the DOE to develop a permanent repository for the storage and disposal of spent nuclear fuel by 1998, the DOE announced that it would not be able to open the repository by 1998 and sought to excuse its performance of these requirements. In November 1997, the DC Circuit issued a decision preventing the DOE from excusing its own delay but refused to order the DOE to begin accepting spent nuclear fuel. Based on this decision and the DOE’s delay, a number of utilities, including APS (on behalf of itself and the other PVNGS owners, including PNM), filed damages actions against the DOE in the Court of Federal Claims. The lawsuits filed by APS alleged that damages were incurred due to DOE’s continuing failure to remove spent nuclear fuel and high-level waste from PVNGS. APS and the DOE entered into a settlement agreement, subsequently extended, that established a process for the payment of claims for costs incurred through December 31, 2025. Under the settlement agreement, APS must submit claims annually for payment of allowable costs. PNM records estimated claims on a quarterly basis. The benefit from the claims is passed through to customers under the FPPAC.

PNM estimates that it will incur approximately $55.6 million (in 2023 dollars) for its share of the costs related to the on-site interim storage of spent nuclear fuel at PVNGS for the remaining term of the operating licenses. PNM accrues these costs as a component of fuel expense as the nuclear fuel is consumed. At December 31, 2024 and 2023, PNM had a liability for interim storage costs of $13.4 million and $11.0 million, which is included in other deferred credits.

PVNGS has sufficient capacity at its on-site Independent Spent Fuel Storage Installation (“ISFSI”) to store all of the nuclear fuel that will be irradiated during the initial operating license period, which ends in December 2027. Additionally, PVNGS has sufficient capacity at its on-site ISFSI to store a portion of the fuel that will be irradiated during the period of extended operation, which ends in November 2047. If uncertainties regarding the U.S. government’s obligation to accept and store spent fuel are not favorably resolved, APS will evaluate alternative storage solutions that may obviate the need to expand the ISFSI to accommodate all of the fuel that will be irradiated during the period of extended operation.

The Energy Transition Act

The Energy Transition Act (“ETA”) sets a statewide standard that requires investor-owned electric utilities to have specified percentages of their electric-generating portfolios be from renewable and zero-carbon generating resources. The ETA requires utilities operating in New Mexico to have renewable portfolios equal to 40% by 2025, 50% by 2030, 80% by 2040, and 100% zero-carbon energy by 2045. The ETA also allows for the recovery of undepreciated investments and decommissioning costs related to qualifying EGUs that the NMPRC has required be removed from retail jurisdictional rates, provided replacement resources to be included in retail rates have lower or zero-carbon emissions. The ETA requires the NMPRC to review and approve utilities’ annual renewable portfolio plans to ensure compliance with the RPS. Also pursuant to the ETA, the New Mexico Environmental Improvement Board adopted standards of performance that limit CO2 emissions to no more than 1,100 lbs. per MWh beginning January 1, 2023 for new and existing coal-fired EGUs with original installed capacities exceeding 300 MW.

The ETA provides for a transition from fossil-fuel generation resources to renewable and other carbon-free resources through certain provisions relating to the abandonment of coal-fired generating facilities. These provisions include the use of energy transition bonds, which are designed to be highly rated bonds that can be issued to finance certain costs of abandoning coal-fired facilities that are retired prior to January 1, 2023 for facilities operated by a “qualifying utility,” or prior to January 1, 2032 for facilities that are not operated by a qualifying utility. The amount of energy transition bonds that can be issued to recover abandonment costs is limited to the lesser of $375.0 million or 150% of the undepreciated investment of the facility as of the abandonment date. Proceeds provided by energy transition bonds must be used only for purposes related to providing utility service to customers and to pay energy transition costs (as defined by the ETA). These costs may include plant decommissioning and coal mine reclamation costs provided those costs have not previously been recovered from customers or disallowed by the NMPRC or by a court order. Proceeds from energy transition bonds may also be used to fund severances for employees of the retired facility and related coal mine and to promote economic development, education and job training in areas impacted by the retirement of the coal-fired facilities. Energy transition bonds must be issued under a NMPRC-approved financing order, are secured by “energy transition property,” are non-recourse to the issuing utility, and are repaid by a non-bypassable charge paid by all customers of the issuing utility. These customer charges are subject to an adjustment mechanism designed to provide for timely and complete payment of principal and interest due under the energy transition bonds.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The ETA also provides that utilities must obtain NMPRC approval of competitively procured replacement resources that shall be evaluated based on their cost, economic development opportunity, ability to provide jobs with comparable pay and benefits to those lost upon retirement of the facility, and that do not exceed emissions thresholds specified in the ETA. In determining whether to approve replacement resources, the NMPRC must give preference to resources with the least environmental impacts, those with higher ratios of capital costs to fuel costs, and those located in the school district of the abandoned facility. The ETA also provides for the procurement of energy storage facilities and gives utilities discretion to maintain, control, and operate these systems to ensure reliable and efficient service.

The ETA has had and will have a significant impact on PNM’s future generation portfolio, including PNM’s retirement of SJGS in 2022. PNM cannot predict the full impact of the ETA with respect to Four Corners or the outcome of its future generating resource abandonment and replacement resource filings with the NMPRC. See additional discussion in Note 17 of PNM’s SJGS and Four Corners Abandonment Applications.

The Clean Air Act

Regional Haze

Pursuant to the CAA, states are required to establish goals for improving visibility in national parks and wilderness areas (also known as Class I areas) and to develop long-term strategies for reducing emissions of air pollutants that cause visibility impairment in their own states and for preventing degradation in other states. States must establish a series of interim goals to ensure continued progress by adopting a new SIP every ten years. In the first SIP planning period, states were required to conduct BART determinations for certain covered facilities, including utility boilers, built between 1962 and 1977 that have the potential to emit more than 250 tons per year of visibility impairing pollution. For all future SIP planning periods, states must evaluate whether additional emissions reduction measures may be needed to continue making reasonable progress toward natural visibility conditions.

SIPs for the second planning period were due in July 2021, which deadline NMED was unable to meet. NMED is currently preparing its SIP for the second compliance period and has notified PNM that it will not be required to submit a regional haze four-factor analysis for SJGS since PNM retired its share of SJGS in 2022. On August 30, 2022, EPA published in the Federal Register an official “Finding of Failure to Submit” for states, including New Mexico, that have not yet submitted a round 2 regional haze SIP. This action by EPA started a 2-year clock for it to issue a Federal Implementation Plan (“FIP”), which deadline has now passed. NMED petitioned the NM Environmental Improvement Board to adopt a proposed SIP. The public hearing that was scheduled for December 18, 2024 was cancelled and a new hearing is scheduled for April 28 to April 30, 2025. PNM submitted comments on the proposed SIP in response to a request for comments by NMED.

Carbon Dioxide Emissions

In 2015, EPA established standards to limit CO2 emissions from power plants, including (1) Carbon Pollution Standards for new, modified, and reconstructed power plants; and (2) the Clean Power Plan for existing power plants. Challengers successfully petitioned the US Supreme Court for a stay of the Clean Power Plan. In 2019, EPA repealed the Clean Power Plan, promulgated the ACE Rule, and revised the implementing regulations for all emission guidelines. The ACE Rule was also challenged, and on January 19, 2021, the DC Circuit issued an opinion in American Lung Association and American Public Health Association v. EPA, et al., vacating the ACE Rule.

Numerous parties sought review by the US Supreme Court, and on June 30, 2022, the Court held that the “generation shifting” approach in the Clean Power Plan exceeded the powers granted to EPA by Congress. Of broader significance in administrative law, the Court’s opinion expressly invoked the “major question” doctrine, which requires rules involving issues of “vast economic or political significance” to be supported by clear statutory authorization. In cases where there is no clear statement of authority, courts need not defer to the agency’s statutory interpretation on “major questions.” The decision sets legal precedent for future rulemakings by EPA and other federal regulatory agencies whereby the agencies’ authority may be limited based upon similar reasoning.

The litigation over the Carbon Pollution Standards remains held in abeyance but could be reactivated by the parties upon a determination by the court that reconsideration of the rule has concluded.

In 2024, EPA adopted regulatory actions under CAA sections 111(b) and (d) to replace the Clean Power Plan and the ACE Rule. The final rules include revised new source performance standards under Section 111(b) for all new natural gas-fired combustion turbines and emission guidelines under Section 111(d) requiring states to develop standards of performance for GHG emissions from existing fossil-fuel-fired electric steam generating units. In the final rules, EPA determined that the

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

standards for existing coal- or gas-fired steam generating units must be based on the use of either CCS (long-term), natural gas co-firing (medium-term), or exempt from the rule via early retirement. The standards for new combustion turbines must be based on CCS (base load), efficient simple cycle design (intermediate load), or lower-emitting fuels (low load). Over a dozen states, several industry groups and some power companies and labor unions have filed challenges to the rule at the DC Circuit, which heard oral arguments on December 6, 2024. However, President Trump issued several executive orders on January 20, 2025, directing his administration to review all agency actions and suspend, revise, or rescind those identified as imposing an undue burden on domestic energy resources, which will likely include the rules for greenhouse gas emissions from new combustion turbines and existing steam generation units.

Because the CAA 111 rule does not contain provisions for existing natural gas units, on March 26, 2024, EPA announced it was opening a non-regulatory docket and issued framing questions to gather input about ways to design a stronger, more durable approach to GHG regulation of existing gas combustion turbines. The docket was open for public comment from March 26, 2024 to May 28, 2024 and the agency held a policy forum to bring stakeholders together to share ideas with EPA and others. Under the new Trump Administration, EPA is unlikely to propose a rule based on this non-regulatory docket.

In 2021, President Biden signed an extensive executive order aimed at addressing climate change concerns domestically and internationally. The order is intended to build on the initial climate-related actions the Biden Administration took on January 20, 2021. It addresses a wide range of issues, including establishing climate change concerns as an essential element of U.S. foreign and security policy, identifying a process to determine the U.S. INDC under the Paris Agreement, and establishing a Special Presidential Envoy for Climate that will sit on the National Security Council. On April 22, 2021, at the Earth Day Summit, as part of the U.S.’s re-entry into the Paris Agreement, President Biden unveiled the goal to cut U.S. emissions by 50% - 52% from 2005 levels by 2030, nearly double the GHG emissions reduction target set by the Obama Administration. The 2030 goal joins President Biden’s other climate goals which include a carbon pollution-free power sector by 2035 and a net-zero emissions economy by no later than 2050. In an executive order issued January 20, 2025, President Trump ordered his administration to withdraw the United States from Paris Agreement and from any agreement, pact, accord, or similar commitment made under the United Nations Framework Convention on Climate Change.

PNM’s review of the GHG emission reductions standards that have or may occur as a result of legislation or regulation is ongoing. We are currently determining what impact, if any, the final rules will have on PNM’s business, results of operations, and financial condition.

National Ambient Air Quality Standards (“NAAQS”)

The CAA requires EPA to set NAAQS for pollutants reasonably anticipated to endanger public health or welfare. EPA has set NAAQS for certain pollutants, including NOx, SO2, ozone, and particulate matter.

NOX Standard – In 2018, EPA published the final rule to retain the current primary health-based NOx standards of which NO2 is the constituent of greatest concern and is the indicator for the primary NAAQS. EPA concluded that the current 1-hour and annual primary NO2 standards are requisite to protect public health with an adequate margin of safety. The rule became effective on May 18, 2018. The State of New Mexico has attained the current NOx NAAQS standards.

SO2 Standard – In 2019, EPA announced its final decision to retain, without changes, the primary health-based NAAQS for SO2. Specifically, EPA retained the current 1-hour standard for SO2, which is 75 parts per billion, based on the 3-year average of the 99th percentile of daily maximum 1-hour SO2 concentrations. In 2021, EPA published in the Federal Register the initial air quality designations for all remaining areas not yet designated under the 2010 SO2 Primary NAAQS. All areas of New Mexico have been designated attainment/unclassifiable through four rounds of designations by EPA.

Ozone Standard – In 2015, EPA finalized the new ozone NAAQS and lowered both the primary and secondary 8-hour standard from 75 to 70 parts per billion. With ozone standards becoming more stringent, fossil-fueled generation units will come under increasing pressure to reduce emissions of NOx and volatile organic compounds since these are the pollutants that form ground-level ozone. During 2017 and 2018, EPA released rules establishing area designations for ozone. In those rules, San Juan County, New Mexico, where Four Corners is located, is designated as attainment/unclassifiable and only a small area in Doña Ana County, New Mexico is designated as marginal non-attainment. Although Afton Generating Station is located in Doña Ana County, it is not located within the small area designated as non-attainment for the 2015 ozone standard. PNM does not believe there will be material impacts to its facilities because of the non-attainment designation of the small area within Doña Ana County. Until EPA approves attainment designations for the Navajo Nation and releases a proposal to implement the revised ozone NAAQS, PNM is unable to predict what impact the adoption of these standards may have on Four Corners. On July 13, 2020, EPA proposed to retain the existing ozone NAAQS based on a review of the full body of currently available

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scientific evidence and exposure/risk information, but on August 21, 2023, EPA announced an entirely new review of the ozone standard. PNM cannot predict the outcome of this matter.

In 2019, EPA issued findings that several states, including New Mexico, had failed to submit interstate transport SIPs for the 2015 8-hour ozone NAAQS, triggering an obligation for EPA to issue a federal implementation plan within two years. In response, NMED submitted a Good Neighbor SIP on July 27, 2021 that demonstrates that there are no significant contributions from New Mexico to downwind problems in meeting the federal ozone standard. On March 15, 2023, EPA Administrator Regan signed a final action imposing a FIP on multiple states but did not include a FIP for New Mexico because the most updated modeling available at the time of the proposal confirmed the state did not contribute to downwind ozone nonattainment or maintenance areas. However, the updated modeling EPA used in the final rule indicated that New Mexico may be significantly contributing to one or more non-attainment or maintenance areas. In light of that modeling result, on February 16, 2024, the EPA published a proposed rule partially disapproving the SIPs for New Mexico and four other states (Arizona, Iowa, Kansas, Tennessee) and expanding the Good Neighbor FIP to apply to these states. The FIP aspect of the proposed rule would have required fossil fuel-fired power plants in these five states to participate in an allowance-based ozone season NOx emissions trading program beginning in 2025, but the outgoing Biden Administration did not finalize the rule, and the new Trump administration is highly unlikely to finalize it.

PM Standard – In 2023, EPA published, in the Federal Register, a proposal to lower the annual fine PM standard to between 9-10 µg/m3 but retain the rest of its PM standards, including the current daily fine PM standard, the daily coarse PM standard, and the secondary PM standards. The final rule was published on March 6, 2024, lowering the primary annual PM 2.5 NAAQS to 9 ug/m3. The rule became effective May 6, 2024, and states will have until March 2032 to attain compliance with the new standard. During the multi-year implementation process, EPA will designate attainment/nonattainment areas by March 6, 2026, and states will submit a State Implementation Plan to EPA by September 6, 2027. This implementation process also applies to the Albuquerque-Bernalillo County Environmental Health Department who may combine efforts with NMED. Bernalillo County does not currently meet the 9 ug/m3 standard which may impact future air permitting activities at Rio Bravo and Reeves Generating Stations if the county is designated as nonattainment. However, even before any designations are made, the new standard is effective for conducting required modeling for permit applications and revisions. The lower standard is expected to result in new nonattainment areas throughout the country and could prompt additional PM control requirements, but PNM cannot predict the impacts of the outcome of future rulemaking.

Cooling Water Intake Structures

In 2014, EPA issued a rule establishing national standards for certain cooling water intake structures at existing power plants and other facilities under the Clean Water Act to protect fish and other aquatic organisms by minimizing impingement mortality (the capture of aquatic wildlife on intake structures or against screens) and entrainment mortality (the capture of fish or shellfish in water flow entering and passing through intake structures).

To minimize impingement mortality, the rule provides operators of facilities, such as Four Corners, seven options for meeting Best Technology Available (“BTA”) standards for reducing impingement. The permitting authority must establish the BTA for entrainment on a site-specific basis, taking into consideration an array of factors, including endangered species and social costs and benefits. Affected sources must submit source water baseline characterization data to the permitting authority to assist in the BTA determination. Compliance deadlines under the rule are tied to permit renewal, including any subject to a schedule of compliance established by the permitting authority in the permit.

In 2018, several environmental groups sued EPA Region IX in the U.S. Court of Appeals for the Ninth Circuit over EPA’s failure to timely reissue the Four Corners NPDES permit. The petitioners asked the court to issue a writ of mandamus compelling EPA Region IX to take final action on the pending NPDES permit by a reasonable date. EPA subsequently reissued the NPDES permit. The permit did not contain conditions related to the cooling water intake structure rule, because EPA determined that the facility had achieved BTA for both impingement and entrainment by operating a closed-cycle recirculation system. Several environmental groups filed a petition for review with EPA’s Environmental Appeals Board (“EAB”) concerning the reissued permit. The environmental groups alleged that the permit was reissued in contravention of the Clean Water Act and did not contain limits or conditions required by EPA’s Effluent Limitations Guidelines (“ELG”) applicable to Four Corners or EPA’s cooling water intake structures rule, among others. EPA withdrew the Four Corners NPDES permit in order to examine the issues raised by the environmental groups and then issued an updated NPDES permit in 2019. The permit was once again appealed to the EAB and was stayed before the effective date, but the EAB issued an order denying the petition for review on September 30, 2020. Thereafter, the Regional Administrator of the EPA signed a notice of final permit decision, and the NPDES permit was issued on November 9, 2020. The permit became effective December 1, 2020. On January 22, 2021, the environmental groups filed a petition for review of the EAB’s decision with the U.S. Court of Appeals for the Ninth

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Circuit. The September 2019 permit remained in effect pending the outcome of this appeal. On March 21, 2022, EPA provided notice in the Federal Register of a proposed settlement agreement with the environmental groups. The parties subsequently executed the settlement agreement as of May 2, 2022. Under the settlement, the lawsuit was administratively closed through September 6, 2023, during which time a third-party consultant spent 12 months sampling discharges from Four Corners and EPA spent three months completing an analysis. On December 1, 2023, EPA issued a modification, effective December 31, 2023, to the NPDES permit that had been issued on November 9, 2020. The modification applies to permit elements related to effluent discharge. PNM cannot predict whether the analysis required to be performed by EPA under the settlement agreement will result in further changes to the NPDES permit but does not anticipate that it will have a material impact on PNM’s financial position, results of operations, or cash flows.

Effluent Limitation Guidelines

In 2013, EPA published proposed revised wastewater ELG establishing technology-based wastewater discharge limitations for fossil fuel-fired electric power plants. EPA signed the final Steam Electric ELG rule in 2015. The final rule, which became effective on January 4, 2016, phased in the new, more stringent requirements in the form of effluent limits for arsenic, mercury, selenium, and nitrogen for wastewater discharged from wet scrubber systems and zero discharge of pollutants in ash transport water that must be incorporated into plants’ NPDES permits. The 2015 rule required each plant to comply between 2018 and 2023 depending on when it needs a new or revised NPDES permit.

The Steam Electric ELG rule was challenged in the U.S. Court of Appeals for the Fifth Circuit by numerous parties. In 2017, EPA signed a notice indicating its intent to reconsider portions of the rule, and the Fifth Circuit issued an order severing the issues under reconsideration and holding the case in abeyance as to those issues. However, the court allowed challenges to other portions of the rule to proceed. In 2019, the Fifth Circuit granted those challenges and issued an opinion vacating several portions of the rule, specifically those related to legacy wastewater and leachate, for which the court deemed the standards selected by EPA arbitrary and capricious.

In 2017, EPA published a final rule for postponement of certain compliance dates. The rule postponed the earliest date on which compliance with the ELG for these waste streams would be required from November 1, 2018 until November 1, 2020. In 2019, EPA published a proposed rule revising the original ELG while maintaining the compliance dates. In 2020, EPA published in the Federal Register the final Steam Electric ELG and Standards for the Steam Electric Power Generating Point Source Category, revising the final 2015 guidelines for both flue gas desulfurization wastewater and bottom ash transport water. The 2020 rule required compliance with new limits as soon as possible on or after October 13, 2021, but no later than December 31, 2025.

In 2021, EPA published notice that it would undertake a supplemental rulemaking to revise the ELG after completing its review of the rules reconsidered in 2020. As part of this process, EPA committed to determine whether more stringent limitations and standards would be appropriate. On March 29, 2023, EPA published the proposed ELG Rule in the Federal Register. The proposed rule included stricter limitations for wastewater discharges for coal-fired facilities, but allowed for flexibilities for those coal-powered facilities that would soon decommission or repower. With this proposed rule EPA extended the date of decommissioning or repowering from December 31, 2028, to December 31, 2032.

On May 9, 2024, EPA published a final rule to further revise the ELG. This final supplemental rule updated the technology-based limitations applicable to flue gas desulfurization wastewater, bottom ash transport water, and legacy wastewater at existing sources, as well as combustion residual leachate at new and existing sources. The 2024 rule was challenged in the U.S. Court of Appeals for the Eighth Circuit, but the court denied motions for stay, so the rule remains in effect.

Reeves Station discharges cooling tower blowdown to a publicly owned treatment plant and no longer holds an NPDES permit; therefore, it is expected that no ELG requirements will be imposed.

See “Cooling Water Intake Structures” above for additional discussion of Four Corners’ current NPDES permit. Four Corners may be required to change equipment and operating practices affecting boilers and ash handling systems, as well as change its waste disposal techniques during the next NPDES permit renewal. PNM is unable to predict the outcome of these matters or a range of the potential costs of compliance.

Santa Fe Generating Station

PNM and NMED are parties to agreements under which PNM has installed a remediation system to treat water from a City of Santa Fe municipal supply well and an extraction well to address gasoline contamination in the groundwater at the site

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of PNM’s former Santa Fe Generating Station and service center. A 2008 NMED site inspection report states that neither the source nor extent of contamination at the site has been determined and that the source may not be the former Santa Fe Generating Station. During 2013 and 2014, PNM and NMED collected additional samples that showed elevated concentrations of nitrate and volatile organic compounds in some of the monitoring wells at the site. In addition, one monitoring well contained free-phase hydrocarbon products. PNM collected a sample of the product for “fingerprint” analysis. The results of this analysis indicated the product was a mixture of older and newer fuels. The presence of newer fuels in the sample suggests the hydrocarbon product likely originated from off-site sources. In 2015, PNM and NMED entered into a memorandum of understanding to address changing groundwater conditions at the site under which PNM agreed to continue hydrocarbon investigation under the supervision of NMED. Qualified costs are eligible for payment through the New Mexico Corrective Action Fund (“CAF”), which is administered by the NMED Petroleum Storage Tank Bureau. In 2019, PNM received notice from NMED that an abatement plan for the site is required to address concentrations of previously identified compounds, unrelated to those discussed above, found in the groundwater. NMED approved PNM’s abatement plan proposal, which covers field work and reporting.

Field work related to the investigation under both the CAF and abatement plan requirements was completed and activities and findings associated with the field work were presented in two separate reports and released to stakeholders in early 2020. Subsequent field work was completed in July 2020 and two reports were released supporting PNM’s contention that off-site sources have impacted, and are continuing to impact, the local groundwater in the vicinity of the former Santa Fe Generating Station.

In 2021, NMED approved both the field work plans required for site characterization and associated work activities which were completed by the end of 2022 and a report was submitted to the NMED in 2023. Groundwater sampling for the abatement plan’s first semiannual work was completed in 2023, and the associated report was completed and submitted to the NMED. In addition, the work plan for the 2023 CAF work was completed and submitted to the NMED in July 2023. NMED approved this work plan in December 2023. The activities from the work plan include the installation of three monitoring wells and additional rounds of groundwater sampling were completed in January 2025. Site wide sampling will take place in 2025, with reports provided to NMED.

The City of Santa Fe has stopped operating its well at the site, which is needed for PNM’s groundwater remediation system to operate. As a result, PNM has stopped performing remediation activities at the site. However, PNM’s monitoring and other abatement activities at the site are ongoing and will continue until the groundwater meets applicable federal and state standards or until the NMED determines remediation is not required, whichever is earlier. PNM is not able to assess the duration of this project or estimate the impact on its obligations if PNM is required to resume groundwater remediation activities at the site. PNM is unable to predict the outcome of these matters.

Coal Combustion Residuals Waste Disposal

CCRs consisting of fly ash, bottom ash, and gypsum generated from coal combustion and emission control equipment at SJGS have been disposed of in the surface mine pits adjacent to the plant. SJGS does not operate any onsite CCR impoundments or landfills. The NMMMD currently regulates mine reclamation activities at the San Juan mine, including placement of CCRs in the surface mine pits, with federal oversight by the OSM. APS disposes of CCRs in onsite ponds and dry storage areas at Four Corners. Ash management at Four Corners is regulated by EPA and the New Mexico State Engineer’s Office.

EPA’s 2015 coal ash rule included a non-hazardous waste determination for coal ash and sets minimum criteria for existing and new CCR landfills and surface impoundments. In 2016, the Water Infrastructure Improvements for the Nation Act (the “WIIN Act”) was signed into law to address critical water infrastructure needs in the U.S. and contained a number of provisions related to CCRs. Among other things, the WIIN Act allowed, but did not require, states to develop and submit CCR permit programs for EPA approval, provided flexibility for states to incorporate EPA’s 2015 rule for CCRs or develop other criteria that are at least as protective as EPA’s rule, and required EPA to approve state permit programs within 180 days of submission by the state. Because states are not required to implement their own CCR permit programs, EPA was required to develop a federal permit program in states that chose not to implement a program, subject to congressional funding. Until state or federal permit programs are in effect, the 2015 rule continues to be self-implementing in nature, subject to enforcement by EPA or citizen groups. For facilities located within the boundaries of Native American reservations, such as the Navajo Nation where Four Corners is located, EPA is required to develop a federal permit program regardless of appropriated funds.

In 2018, EPA published a rule that constitutes “Phase One, Part One” of its ongoing reconsideration and revision of the 2015, CCR rule. The final Phase One, Part One rule extended the deadline to allow EGUs with unlined impoundments or that fail to meet the uppermost aquifer requirement to continue to receive coal ash until October 31, 2020, which was again

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extended by subsequent amendments. The rule also authorized a “Participating State Director” or EPA to approve suspension of groundwater monitoring requirements and to issue certifications related to the location restrictions, design criteria, groundwater monitoring, remedy selection and implementation. The rule also modified groundwater protection standards for certain constituents, which include cobalt, molybdenum, lithium, and lead without a maximum contamination level.

In 2019, EPA published a second round of proposed revisions, which are commonly referred to as the “Phase Two” revisions, to address reporting and accessibility to public information, “CCR piles” and “beneficial use” definitions, and the requirements for management of CCR piles. EPA reopened and extended the Phase Two comment period several times. To date, EPA has not yet finalized provisions in Phase Two related to beneficial use of CCR and CCR piles.

Since its Phase Two proposal, EPA has finalized two other rules addressing various CCR rule provisions. In 2020, EPA promulgated its proposed Holistic Approach to Closure Part A (“Part A”), which proposed a new deadline of August 31, 2020, for companies to initiate closure of unlined CCR impoundments. In accordance with the DC Circuit Court of Appeals’ vacatur of portions of the 2015 CCR Rule, Part A also changed the classification of compacted soil-lined or clay-lined surface impoundments from “lined” to “unlined”, triggering closure or retrofit requirements for those impoundments. In addition, Part A delineated a process for owners/operators to submit requests for alternative closure deadlines based on lack of alternate disposal capacity and gave operators of unlined impoundments until April 11, 2021 to cease receipt of waste at these units and initiate closure.

EPA also issued the Holistic Approach to Closure Part B (“Part B”) in 2020, which delineated the process for owners/operators to submit alternate liner demonstrations for clay-lined surface impoundments that could otherwise meet applicable requirements. This rule did not include beneficial use of CCR for closure, which EPA explained would be addressed in subsequent rulemaking actions. On May 18, 2023, EPA published a proposed rule on the regulatory requirements for inactive surface impoundments at inactive facilities and a new category of regulated unit called a CCR management unit (“CCRMU”), including groundwater monitoring, corrective action, closure, and post-closure care requirements for all CCR management units (regardless of how or when that CCR was placed), and several technical corrections to the existing regulations. Comments on the proposed rule were due July 17, 2023.

On May 8, 2024, EPA published a final rule that extended federal CCR regulatory requirements to (1) inactive CCR surface impoundments at inactive utilities and (2) CCRMU (Legacy Rule), including CCR impoundments and landfills that closed prior to the effective date of the 2015 CCR rule, inactive CCR landfills, and other areas where CCR was managed directly on the land. The rule became effective on November 8, 2024. EPA included deferral options for smaller CCRMU containing between one and 1,000 tons of CCR, CCRMU located beneath critical infrastructure or large buildings or structures vital to the continuation of current site activities, and CCRMU that closed prior to the effective date of the new rule (subject to certain eligibility conditions). EPA also codified the controversial definitions of infiltration and liquids that were litigated in the DC Circuit. Six petitions for review of the Legacy Rule were filed and were consolidated into one case by the DC Circuit. The Utility Solid Waste Activities Group, of which TXNM Energy is a member, is a petitioner jointly with the National Rural Electric Cooperative Association, and American Public Power Association.

As of the effective date of the rule, one CCRMU was identified at SJGS. SJGS is required, at a minimum, to conduct a two-part evaluation of historic and current CCRMUs with reporting due dates of February 9, 2026, and February 8, 2027, with each report posted to a company website by the due date.

At this time, PNM is still evaluating the financial impacts of this final regulation for Four Corners. Initial CCRMU site surveys are expected to be completed by February 2026 with final site investigation reports expected to be finalized by February 2027. Based on the information available to the Company at this time, PNM cannot reasonably estimate the fair value of the entire CCRMU asset retirement obligation. PNM cannot predict the outcome of the CCRMU site evaluations and investigations, or how these outcomes might affect the associated costs, which might have a material impact on PNM’s operations, financial position, or cash flows.

In 2020, EPA published a proposed rule establishing a federal permitting program for the handling of CCR within the boundaries of Native American reservations and in states without their own federally authorized state programs. Permits for units within the boundaries of Native American reservations would be due 18 months after the effective date of the rule. EPA projected finalizing the rule in October 2024 but still has not submitted a final version to OMB. Given the change in Administration, it is not clear whether or when EPA will finalize the rule. EPA has coordinated with the affected permits for the three facilities with CCR disposal units located on Native American lands. PNM cannot predict the outcome of EPA’s rulemaking activity or the outcome of any related litigation, and whether or how such a ruling would affect operations at Four Corners.

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EPA’s CCR rule does not cover mine placement of coal ash. In the preamble to its 2015 rule, EPA explained that the United States Office of Surface Mining Reclamation and Enforcement (“OSM”) and, as necessary, EPA would address the management of CCR in mine fills in a separate regulatory action, recognizing OSM’s expertise in this area. EPA’s decision to defer to OSM was based on a recommendation from the National Academy of Sciences (“NAS”), which was commissioned by Congress in 2006 to investigate the health, safety and environmental risks associated with the use of CCR for mine reclamation. The NRC report recommended that enforceable federal standards be established for the disposal of CCR in mine fills to ensure that states have specific authority and that states implement adequate safeguards. In 2007, OSM published an advance notice of proposed rulemaking on the placement of CCR at mine sites. In that notice, OSM explained its intent to develop the proposed regulations based on its existing authority under the Surface Mining Control and Reclamation Act (“SMCRA”). Since 2007, however, OSM has not taken any further action to advance this rulemaking. PNM cannot predict the outcome of OSM’s proposed rulemaking regarding CCR regulation, including mine placement of CCRs, or whether OSM’s actions will have a material impact on PNM’s operations, financial position, or cash flows.

As noted above, SJGS does not operate any onsite CCR impoundments or landfills that are regulated under the 2015 CCR rule, and as of November 8, 2024, identified only one CCRMU that would be regulated under the Legacy Rule. That CCRMU has since been removed from that unit. PNM would seek recovery from its retail customers of all CCR costs for jurisdictional assets that are ultimately incurred.

Utilities that own or operate CCR disposal units, such as those at Four Corners, as indicated above, were required to collect sufficient groundwater sampling data to initiate a detection monitoring program. Four Corners completed the analysis for its CCR disposal units, which identified several units that needed corrective action or needed to cease operations and initiate closure by April 11, 2021. Work is ongoing. Four Corners continues to gather additional groundwater data and perform remedial evaluations and activities. At this time, PNM does not anticipate its share of the cost to complete these corrective actions to close the CCR disposal units, or to gather and perform remedial evaluations on groundwater at Four Corners, will have a significant impact on its operations, financial position, or cash flows.

Other Commitments and Contingencies

Coal Supply

Four Corners

APS purchases all of Four Corners’ coal requirements from NTEC, an entity owned by the Navajo Nation, under the Four Corners CSA that expires in 2031. The coal comes from reserves located within the Navajo Nation. The contract provides for pricing adjustments over its term based on economic indices and certain minimum payments that may be required if no deliveries of coal are taken. As of December 31, 2024 those minimum payments were $42.5 million for 2025, $85.9 million for 2026 and 2027, $89.8 million for 2028 and 2029, and $71.0 million for 2030 and thereafter. PNM’s share of the coal costs is being recovered through the FPPAC.

Coal Mine Reclamation

As indicated under Coal Combustion Residuals Waste Disposal above, SJGS disposed of CCRs in the surface mine pits adjacent to the plant and Four Corners disposes of CCRs in ponds and dry storage areas.

Under the terms of the SJGS CSA, PNM and the other SJGS owners are obligated to compensate WSJ LLC for all reclamation costs associated with the supply of coal from the San Juan mine. PNM and Westmoreland have entered into an agreement under which mine reclamation services for SJGS would be provided. A mine reclamation cost study was completed in the first quarter of 2024 and PNM remeasured its liability, which resulted in an increase in overall reclamation costs of $20.9 million, due primarily to higher inflationary factors. As a result, PNM recorded the increase in the liability related to the underground mine of $17.0 million as a regulatory asset on the Consolidated Balance Sheets. Due to the NMPRC cap on the amount that can be collected from retail customers for final reclamation of the surface mines at $100.0 million, PNM was required to record $4.0 million of the increase related to the surface mine liability plus an additional $0.5 million, related to other costs, as a regulatory disallowance on the Consolidated Statements of Earnings for the year ended December 31, 2024. In the third quarter of 2024, PNM and Westmoreland amended the mine reclamation services agreement to update the base rates for the costs of reclamation activities, which resulted in an increase in overall reclamation costs of $12.1 million. As a result, PNM recorded the increase in the liability related to the underground mine of $6.0 million as regulatory assets on the Consolidated Balance Sheets and the increase of $6.1 million related to the surface mine as a regulatory disallowance on the Consolidated Statements of Earnings for the year ended December 31, 2024.

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PNM’s estimate of the costs necessary to reclaim the mine that serves SJGS is subject to many assumptions, including the timing of reclamation, generally accepted practices at the time reclamation activities occur, and current inflation and discount rates. PNM cannot predict the ultimate cost to reclaim the mine that serves SJGS and would seek to recover all costs related to reclaiming the underground mine from its customers but could be exposed to additional loss related to surface mine reclamation. In connection with certain mining permits relating to the operation of the San Juan mine, Westmoreland was required to post reclamation bonds of $118.7 million with the NMMMD. In order to facilitate the posting of reclamation bonds by sureties on behalf of Westmoreland, TXNM entered into the WFB LOC Facility under which letters of credit aggregating $30.3 million have been issued.

A coal mine reclamation study for the surface mine that serves Four Corners was issued in December 2024. The study reflected operation of the mine through 2031, the term of the Four Corners CSA. PNM remeasured its liability, which resulted in a decrease in overall reclamation costs of $1.6 million, due primarily to lower overhead costs, contractor management costs, and tax and royalties. Due to the NMPRC cap on the amount that can be collected from retail customers for final reclamation of the surface mines at $100.0 million, PNM recorded the decrease related to the surface mine liability as a regulatory disallowance on the Consolidated Statements of Earnings for the year ended December 31, 2024.

Based on the most recent estimates, PNM’s remaining payments for mine reclamation, in future dollars, are estimated to be $51.1 million for the surface mines at both SJGS and Four Corners and $62.7 million for the underground mine at SJGS as of December 31, 2024. At December 31, 2024 and 2023, liabilities, in current dollars, of $38.3 million and $50.0 million for surface mine reclamation and $52.9 million and $26.2 million for underground mine reclamation were recorded in other deferred credits.

The SJGS owners are parties to a reclamation trust funds agreement to provide financial assurance for post-term coal mine reclamation obligations. The trust funds agreement requires each owner to enter into an individual trust agreement with a financial institution as trustee, create an irrevocable reclamation trust, and meet year-end funding targets set by funding curves that are approved by the SJGS ownership. PNM began using its mine reclamation trust to pay for final mine reclamation costs in April 2023. Because the trust agreement requires meeting specific funding targets at year end, it may be necessary for PNM to make additional contributions to meet those targets. PNM funded $27.3 million in 2024, $2.7 million in 2023, and $10.0 million in 2022. Based on PNM’s reclamation trust fund balance at December 31, 2024 and current funding curve targets, PNM anticipates contributing $1.0 million in 2025 and $0.6 million in 2026.

Under the Four Corners CSA, PNM is required to fund its share of estimated final reclamation costs in annual installments into an irrevocable escrow account solely dedicated to the final reclamation cost of the surface mine at Four Corners. PNM contributed $3.2 million in 2024, $0.2 million in 2023, and $2.4 million in 2022 and anticipates providing additional funding of $0.5 million in 2025 and $0.5 million in 2026.

PNM recovers from retail customers reclamation costs associated with the underground mine. However, the NMPRC capped the amount collected from retail customers for final reclamation of the surface mines at $100.0 million for both SJGS and Four Corners. If future estimates increase the liability for surface mine reclamation, the excess would be expensed at that time. The impacts of changes in New Mexico state law as a result of the enactment of the ETA and regulatory determinations made by the NMPRC may also affect PNM’s financial position, results of operations, and cash flows. See additional discussion regarding PNM’s SJGS and Four Corners Abandonment Applications in Note 17. PNM is currently unable to determine the outcome of these matters or the range of possible impacts.

SJGS Decommissioning

On November 9, 2021, the San Juan County Commission approved the Coal-Fired Electricity Generating Facility Demolition and Remediation Ordinance (“Ordinance 121”), requiring the full demolition of SJGS upon its complete and permanent closure. Ordinance 121 required the SJGS owners to submit a proposed demolition and remediation plan no later than three months after SJGS was retired. The SJGS owners submitted the decommissioning and remediation plan on December 28, 2022. In connection with restructuring of the SJGS ownership on December 31, 2017, PNM and the other SJGS owners entered into the San Juan Decommissioning and Trust Funds Agreement, which requires PNM to fund its ownership share of final decommissioning costs into an irrevocable trust. Under the agreement, PNM made an initial funding of $14.7 million in December 2022 and made additional contributions of $7.0 million in 2024. The amount and timing of additional trust funding is subject to revised decommissioning cost studies and agreement among the SJGS owners. PNM began using its decommissioning trust to pay for demolition and decommissioning costs in October 2023. PNM has posted a surety bond in the amount of $46.0 million in connection with certain environmental decommissioning obligations and must maintain the bond or other financial assurance until those obligations are satisfied. The surety bond only represents a liability if the SJGS owners fail to deliver on its contractual liability.

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December 31, 2024, 2023 and 2022

PNM records its share of the SJGS decommissioning obligation as an ARO on its Consolidated Balance Sheets. Studies on the decommissioning costs of SJGS are performed periodically and revisions to the ARO liability are recorded. In the third quarter of 2022, a new decommissioning cost study was completed, which required PNM to remeasure its SJGS decommissioning ARO. The new study resulted in an estimated decrease to PNM’s share of the decommissioning obligation of $21.1 million, which was recorded in September 2022.

PVNGS Liability and Insurance Matters

Public liability for incidents at nuclear power plants is governed by the Price-Anderson Nuclear Industries Indemnity Act, which limits the liability of nuclear reactor owners to the amount of insurance available from both commercial sources and an industry-wide retrospective payment plan. The insurance limit is subject to an adjustment every five years based upon the aggregate percentage change in the CPI. The most recent adjustment took effect on January 1, 2024. As of that date, in accordance with this act, the PVNGS participants are insured against public liability exposure for a nuclear incident up to $16.3 billion per occurrence. PVNGS maintains the maximum available nuclear liability insurance in the amount of $500 million, which is provided by American Nuclear Insurers. The remaining $15.8 billion is provided through a mandatory industry-wide retrospective assessment program. If losses at any nuclear power plant covered by the program exceed the accumulated funds, PNM could be assessed retrospective premium adjustments. The maximum retrospective premium per reactor under the program for each nuclear liability incident is $165.9 million, subject to a maximum annual premium of $24.7 million per incident. Based on PNM’s ownership interest in the three units, PNM’s maximum retrospective premium per incident for all three units is $36.3 million, with a maximum annual payment limitation of $5.4 million, to be adjusted periodically for inflation.

The PVNGS participants maintain insurance for damage to, and decontamination of, property at PVNGS in the aggregate amount of $2.8 billion, a substantial portion of which must first be applied to stabilization and decontamination. These coverages are provided by Nuclear Electric Insurance Limited (“NEIL”). The primary policy offered by NEIL contains a sublimit of $2.25 billion for non-nuclear property damage. If NEIL’s losses in any policy year exceed accumulated funds, PNM is subject to retrospective premium adjustments of $5.1 million. The insurance coverages discussed in this, and the previous paragraph are subject to certain policy conditions, sublimits, and exclusions.

(17)Regulatory and Rate Matters

The Company is involved in various regulatory matters, some of which contain contingencies that are subject to the same uncertainties as those described in Note 16.

PNM

New Mexico General Rate Case

2025 Rate Request

On June 14, 2024, PNM filed an application with the NMPRC for a general increase in retail electric rates. The proposed base rate changes would be implemented in two phases, with the first phase effective July 1, 2025 and the second phase effective January 1, 2026. Key aspects of PNM’s request include:

•Recovery on total rate base of $3.0 billion, based on a FTY with the 12 months ending June 30, 2026

•An increase of $174.3 million in retail revenues, comprised of a $92.2 million increase in base rates and a $82.1 million increase in revenues collected under PNM’s FPPAC

•Drivers of revenue deficiency:

◦Needed investments across distribution, transmission, and generation facilities to ensure safe, reliable delivery of electricity

◦Increased operations and maintenance expenses to meet operational needs, including wildfire risk mitigation

◦Costs associated with ESAs, previously approved by the NMPRC, necessary to serve our customers

◦ROE of 10.45%

◦Proposed capital structure of 52.5% equity

◦An increased cost of borrowing

◦Adjustments to Four Corners depreciation rates to recover remaining plant investments through July 2031, the expected abandonment date of the facility

•Proposed ratemaking treatment of ESAs to be recovered through PNM’s FPPAC beginning July 1, 2025

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December 31, 2024, 2023 and 2022

On November 26, 2024, PNM filed an unopposed comprehensive stipulation with the NMPRC. Key components agreed upon by the signatories are as follows:

•Overall revenue requirement increase of $105.0 million with the first phase effective July 1, 2025 and the second phase effective April 1, 2026

•ROE of 9.45%

•Capital structure of 51.0% equity

•Maintain currently approved depreciation rates for Four Corners as established in PNM’s 2024 Rate Change and PNM’s NM 2015 Rate Case

•Modification of PNM’s current amortization period through December 31, 2028 on the unprotected Excess Deferred Federal Income Taxes (“EDFIT”) regulatory liability to reflect amortization of remaining unprotected EDFIT through December 31, 2027

•Costs associated with ESAs shall be recovered through base rates

◦PNM will establish a regulatory asset or regulatory liability for the difference in actual ESA costs compared to the forecasted $82.1 million included in base rates in the test period and thereafter until new rates are effective from PNM’s next general rate case filing. The regulatory asset or regulatory liability will be subject to NMPRC approval in PNM’s next rate case

•PNM will establish a regulatory liability associated with investment tax credits for the Sandia energy storage system as proposed in its application

•PNM will establish a regulatory liability equal to the return on legacy meters currently included in rates, as the legacy meters are retired during PNM’s deployment of its grid modernization plan approved in PNM’s Grid Modernization Application

A hearing was held on February 17 and 18, 2025. PNM cannot predict the outcome of this matter.

2024 Rate Change

On December 5, 2022, PNM filed an application with the NMPRC for a general increase in retail electric rates including recovery on total rate base of $2.7 billion based on a calendar year 2024 FTY, an increase of $63.8 million in retail non-fuel revenues, and an ROE 10.25%. The application also proposed ratemaking treatment of PVNGS Leased Interest and testimony supporting the prudence of PNM’s decisions to renew the five leases and repurchase 64.1 MW of PVNGS Unit 2 capacity.

On January 3, 2024, the NMPRC issued a final order authorizing PNM to implement an increase in non-fuel base rates of $15.3 million, effective for service beginning January 15, 2024. Major components of the difference compared to PNM’s application include:

•A ROE of 9.26%.

•A capital structure of 49.61% equity, 50.10% debt, and 0.29% preferred stock.

•Finding of imprudence regarding PNM’s decision to remain in Four Corners and a remedy for the imprudence resulting in a disallowance of $81.0 million to PNM’s total Four Corners net book value.

•Approval of $51.3 million of PNM’s requested $96.3 million regulatory asset for PVNGS undepreciated investments, but disallowance of a return on the remaining $45.0 million or any CWIP associated with it.

•Requiring that the $38.4 million regulatory liability associated with leased capacity at PVNGS after the Unit 1 lease expired on January 15, 2023, be returned to ratepayers over two years through a separate rate rider.

•The approval of new depreciation rates, reflecting shorter useful lives, of PNM’s gas plants with service lives and depreciable lives extending beyond January 1, 2045, which would include PNM’s La Luz and Luna generating stations.

•The approval of PNM’s TOD pilot program, with a requirement to make annual compliance filings and to adjust certain rate schedules.

As a result of the NMPRC final order in the 2024 Rate Change, during the year ended December 31, 2023, PNM recorded a regulatory disallowance of $55.5 million on the Consolidated Statement of Earnings and a corresponding reduction to Utility Plant, after accounting for previous impairments, to reflect the remedy adopted in the Final Order for Four Corners. In addition, PNM recorded a reduction to electric operating revenues of $38.4 million with a corresponding current regulatory liability of $19.2 million and a deferred regulatory liability of $19.2 million for the PVNGS rate refunds that will be returned to customers over a two-year period. PNM also recorded a regulatory disallowance of $8.2 million on the Consolidated Statement of Earnings and a corresponding reduction to Utility Plant for the disallowance of CWIP from PVNGS.

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December 31, 2024, 2023 and 2022

In March 2024, notice of appeals were separately filed with the NM Supreme Court by NEE and PNM, and a joint notice of appeal was filed by the NM Department of Justice, Bernalillo County, and ABCWUA. NEE’s appeal was subsequently consolidated with the joint notice of appeal. In the statements of issues submitted in the parties’ appellate dockets, PNM took issue with the NMPRC’s ruling on capital structure; other appellants primarily challenged the NMPRC rulings related to Four Corners and Palo Verde cost recovery. PNM cannot predict the outcome of this matter.

Renewable Energy Portfolio Standard

As discussed in Note 16, the ETA amends the REA including removal of diversity requirements and certain customer caps and exemptions relating to the application of the RPS under the REA. The REA provides for streamlined proceedings for approval of utilities’ renewable energy procurement plans, assures that utilities recover costs incurred consistent with approved procurement plans, and requires the NMPRC to establish a Reasonable Cost Threshold (“RCT”) for the procurement of renewable resources to prevent excessive costs being added to rates. The ETA sets a RCT of $60 per MWh, adjusted for inflation, using an average annual levelized resource cost basis. PNM makes renewable procurements consistent with the NMPRC approved plans and recovers certain renewable procurement costs from customers through the renewable energy rider billed on a KWh basis.

Included in PNM’s approved procurement plans are the following renewable energy resources:

•158 MW of PNM-owned solar-PV facilities

•A PPA through 2044 for the output of New Mexico Wind, having a current aggregate capacity of 200 MW, and a PPA through 2035 for the output of Red Mesa Wind, having an aggregate capacity of 102 MW

•A PPA through 2040 for 140 MW of output from La Joya Wind II

•A PPA through 2042 for the output of the Lightning Dock Geothermal facility with a capacity of 11 MW

•Solar distributed generation, aggregating 308.5 MW at December 31, 2024, owned by customers or third parties from whom PNM purchases any net excess output and RECs

The NMPRC has authorized PNM to recover certain renewable procurement costs through a rate rider billed on a per KWh basis. In its 2024 renewable energy procurement plan, which became effective on January 1, 2024, PNM proposed to collect $59.0 million for the year. On June 3, 2024, PNM filed its renewable energy procurement plan for 2025 which proposes to collect $58.7 million for the year. PNM did not propose any new resource procurements, and the plan states that existing projects are anticipated to exceed the applicable RPS standards of 2025, despite the standard doubling. On September 11, 2024, a public hearing was held and on October 11, 2024, the hearing examiners issued a RD recommending approval of all PNM’s requests. On November 14, 2024, the NMPRC issued an order adopting the recommended decision. The 2025 renewable energy procurement plan became effective on January 1, 2025.

The following sets forth PNM’s revenues recorded for the renewable energy rider:


Year Ended						Annual Revenues
						(In millions)
2022						$60.3
2023						56.9
2024						52.0

Under the renewable rider, if PNM’s earned rate of return on jurisdictional equity in a calendar year, adjusted for items not representative of normal operations, exceeds the NMPRC-approved rate by 0.5%, PNM is required to refund the excess to customers during May through December of the following year. PNM does not expect to exceed the limitation in 2024.

Energy Efficiency and Load Management

Program Costs and Incentives/Disincentives

The New Mexico EUEA requires public utilities to achieve specified levels of energy savings and to obtain NMPRC approval to implement energy efficiency and load management programs. The EUEA requires the NMPRC to remove utility disincentives to implementing energy efficiency and load management programs and to provide incentives for such programs. The NMPRC has adopted a rule to implement this act. PNM’s costs to implement approved programs and incentives are recovered through a rate rider. During the 2019 New Mexico legislative session, the EUEA was amended to, among other

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December 31, 2024, 2023 and 2022

things, include a decoupling mechanism for disincentives, preclude a reduction to a utility’s ROE based on approval of disincentive or incentive mechanisms, establish energy savings targets for the period 2021 through 2025, and require that annual program funding be 3% to 5% of an electric utility’s annual customer bills excluding gross receipt taxes, franchise and right-of-way access fees, provided that a customer’s annual cost does not exceed seventy-five thousand dollars.

In 2020, PNM received approval for energy efficiency and load management programs to be offered in 2021, 2022, and 2023. The program portfolio consisted of twelve programs with a total annual budget of $31.4 million in 2021, $31.0 million in 2022, and $29.6 million in 2023. The program included an annual base incentive of 7.1% of the portfolio budget if PNM were to achieve energy savings of at least 80 GWh in a year. The incentive increases if PNM is able to achieve savings greater than 94 GWh in a year.

In 2023, PNM filed an application for energy efficiency and load management programs to be offered in 2024, 2025, and 2026 (the “2024 Plan”). The 2024 Plan proposed to continue ten existing energy efficiency programs with modification and a total annual budget of $34.5 million in 2024, $35.4 million in 2025, and $36.5 million in 2026. The application also sought approval of an annual base incentive of 7.1% of the portfolio budget and a sliding scale that provides additional incentive for additional energy saved as a percentage of program cost, up to the maximum allowed by the energy efficiency rule which for PNM is 8.82%. On January 26, 2024, the hearing examiners in the case issued a RD. The RD largely approved PNM’s 2024 Plan but with modifications that include the pursuit of demand response resources, additional analysis in future filings, adjustments to certain energy efficiency programs, and modification of the incentive sliding scale cap to reflect a new maximum. On March 7, 2024, the NMPRC approved the RD in its entirety.

2020 Decoupling Petition

As discussed above, the legislature amended the EUEA to, among other things, include a decoupling mechanism for disincentives. On May 28, 2020, PNM filed a petition for approval of a rate adjustment mechanism that would decouple the rates of its residential and small power rate classes. Decoupling is a rate design principle that severs the link between the recovery of fixed costs of the utility through volumetric charges. On July 13, 2020, NEE, ABCWUA, the City of Albuquerque, and Bernalillo County filed motions to dismiss the petition on the grounds that approving PNM’s proposed rate adjustment mechanism outside of a general rate case would result in retroactive ratemaking and piecemeal ratemaking. The motions to dismiss also alleged that PNM’s proposed rate adjustment mechanism is inconsistent with the EUEA. On October 2, 2020, PNM requested an order to vacate the public hearing, scheduled to begin October 13, 2020, and staying the proceeding until the NMPRC decides whether to entertain a petition to issue a declaratory order resolving the issues raised in the motions to dismiss. On October 7, 2020, the hearing examiner approved PNM’s request to stay the proceeding and vacate the public hearing and required PNM to file a petition for declaratory order by October 30, 2020. On October 30, 2020, PNM filed a petition for declaratory order asking the NMPRC to issue an order finding that full revenue decoupling is authorized by the EUEA. On November 4, 2020, ABCWUA and Bernalillo County jointly filed a competing petition asking the NMPRC to issue a declaratory order on the EUEA’s requirements related to disincentives. On March 17, 2021, the NMPRC issued an order granting the petitions for declaratory order, commencing a declaratory order proceeding to address the petitions and appointing a hearing examiner to preside over the declaratory order proceeding.

On January 14, 2022, the hearing examiner issued a RD recommending the NMPRC find that the EUEA does not mandate the NMPRC to authorize or approve a full decoupling mechanism, defining full decoupling as limited to energy efficiency and load management measures and programs. The RD also states that a utility may request approval of a rate adjustment mechanism to remove regulatory disincentives to energy efficiency and load management measures and programs through a stand-alone petition, as part of the utility’s triennial energy efficiency application or a general rate case and that PNM is not otherwise precluded from petitioning for a rate adjustment mechanism prior to its next general rate case. Finally, the RD stated that the EUEA does not permit the NMPRC to reduce a utility’s ROE based on approval of a disincentive removal mechanism founded on removing regulatory disincentives to energy efficiency and load management measures and programs. The RD does not specifically prohibit a downward adjustment to a utility’s capital structure, based on approval of a disincentive removal mechanism. On April 27, 2022, the NMPRC issued an order adopting the RD in its entirety. On May 24, 2022, PNM filed a notice of appeal with the NM Supreme Court. The NM Supreme Court held oral arguments on November 13, 2023. On May 13, 2024, the NM Supreme Court issued a decision finding that the EUEA allows a utility to propose full decoupling mechanisms. The NM Supreme Court did not address the second issue regarding a downward adjustment to a utility’s capital structure based on approval of disincentive removal mechanism. No declaratory order was issued by the NMPRC. This matter is now concluded.

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December 31, 2024, 2023 and 2022

Integrated Resource Plans

NMPRC rules require that investor-owned utilities file an IRP every three years. The IRP is required to cover a 20-year planning period and contain an action plan covering the first three years of that period. On September 14, 2022, the NMPRC adopted revisions to the IRP Rule. The new rule revamps and modernizes the planning process to accommodate increased stakeholder involvement. The IRP Rule establishes a collaborative facilitated process for a utility and stakeholders to agree on a statement of need for potential new or additional resources, as well as an action plan to guide procurement or development of resources to meet the stated need. A most-cost-effective portfolio of resources shall be derived from the statement of need analysis. The statement of need and action plan must be accepted before the utility begins the resource solicitation process pursuant to the IRP Rule. Following acceptance of the statement of need and action plan, a utility will provide the NMPRC and intervenors drafts of the RFP and a timeline for issuing, receiving, evaluating, and ranking bids. The NMPRC will then appoint an Independent Monitor (“IM”) to oversee the RFP process, which allows for parties and the IM to comment on the RFP consistency with the IRP, after which the utility issues the RFP. Within 120 days of receiving bids the utility shall provide the IM with results including pricing and non-price evaluation criteria, ranking of bids, chosen portfolio and alternatives that also meet the needs; the IM then rules on the fairness of the RFP execution. Acceptance of the statement of need and action plan will not constitute a finding of prudency or pre-approval of costs associated with the additional resources. Following the RFP and IM processes, the utility may apply for approvals, and any costs incurred to implement the action plan will be considered in a general rate case and/or resource acquisition proceeding. On October 14, 2022, PNM and other investor-owned utilities filed motions for rehearing with the NMPRC. On October 26, 2022, the NMPRC issued an order partially granting and partially denying certain aspects of PNM’s and the other investor-owned utilities’ motions for rehearing. On November 2, 2022, the NMPRC adopted an amended IRP Rule. On December 2, 2022, PNM filed an appeal with the NM Supreme Court. Two other investor-owned utilities also separately filed appeals at the NM Supreme Court. On January 3, 2023, PNM and the two other investor-owned utilities filed statements of issues with the NM Supreme Court. Among other things, the investor-owned utilities question whether the IRP Rule exceeds the NMPRC authority by imposing unauthorized requirements on utilities and extending NMPRC jurisdiction through over-broad interpretation of the statutes and state that the IRP Rule is contrary to law in its provisions for NMPRC regulation of a utility’s resource procurement decision-making. On June 5, 2023, PNM and the other two investor-owned utilities filed their Joint Brief in Chief and request for oral arguments at the NM Supreme Court. The NM Supreme Court held oral arguments on May 13, 2024. On December 6, 2024, the NM Supreme Court issued a decision finding that the amended regulations do not exceed the statutory scope of the EUEA.

2023 IRP

On December 15, 2023, PNM filed its 2023 IRP with a continued focus on a carbon-free energy system by 2040. The plan highlights the need for the significant sustained addition of resources over the next two decades, replacing retiring or expiring capacity, meeting concurrent load growth, while reducing the carbon intensity of PNM’s portfolio. On April 4, 2024, the NMPRC accepted PNM’s 2023 IRP.

On December 30, 2024, PNM issued its 2029-2032 RFP for at least 900 MW of new energy resources to come online between 2029 and 2032, with at least 500 MW needed by 2030. The RFP is consistent with the needs identified in PNM’s 2023 IRP, which identified a range of 900 to 2,900 MW of new capacity needed by 2032, depending on the type of resources selected. The 2029-2032 RFP is anticipated to identify potential replacement resources for PNM’s current natural gas generation capacity as well as PNM’s ownership interest in Four Corners.

Abandonment Applications made under the ETA

As discussed in Note 16, the ETA provides for a transition from fossil-fueled generating resources to renewable and carbon-free resources by allowing utilities to issue energy transition bonds related to the retirement of certain coal-fired generating facilities, to qualified investors.

SJGS Abandonment Application

In 2019, PNM filed a Consolidated Application for the Abandonment and Replacement of SJGS and Related Securitized Financing Pursuant to the ETA. In 2023, PNM, along with intervening parties reached a unanimous settlement which was approved by the NMPRC. As a result, PNM recorded a $128.7 million reduction to electric operating revenues in the Consolidated Statement of Earnings and a corresponding current regulatory liability on the Consolidated Balance Sheets as of and for the year ended December 31, 2023. In addition, PNM recorded a regulatory disallowance of $3.3 million on the Consolidated Statement of Earnings and a corresponding decrease to deferred regulatory assets on the Consolidated Balance

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December 31, 2024, 2023 and 2022

Sheets as of and for the year ended December 31, 2023, to reflect PNM’s agreement to withdraw its request for regulatory assets associated with prefunding of ETA state administered funds and legal costs associated with this matter.

Four Corners Abandonment Application

In 2020, PNM entered into the Four Corners Purchase and Sale Agreement with NTEC, pursuant to which PNM agreed to sell its 13% ownership interest (other than certain transmission assets) in Four Corners to NTEC, contingent upon NMPRC approval. In connection with the sale, PNM would make payments of $75.0 million to NTEC for relief from its obligations under the coal supply agreement for Four Corners after December 31, 2024. PNM made an initial payment to NTEC of $15.0 million in November 2020, subject to refund with interest upon termination of the Four Corners Purchase and Sale Agreement prior to closing. Under the terms of the Four Corners Purchase and Sale Agreement, upon receipt of the NMPRC approval, PNM was expected to make a final payment of $60.0 million.

On January 8, 2021, PNM filed the Four Corners Abandonment Application, which sought NMPRC approval to exit PNM’s share of Four Corners as of December 31, 2024, and issuance of approximately $300 million of Securitized Bonds as provided by the ETA. On December 15, 2021, the NMPRC issued a final order denying approval of the Four Corners Abandonment Application and the corresponding request for issuance of securitized financing. On December 22, 2021, PNM filed a Notice of Appeal with the NM Supreme Court of the NMPRC decision to deny the application and on July 6, 2023, the NM Supreme Court affirmed the NMPRC decision concluding that the NMPRC reasonably and lawfully denied PNM’s application for abandonment. As a result of the NM Supreme Court's decision to uphold the NMPRC's denial, the Consolidated Statements of Earnings for the year ended December 31, 2023 reflect a regulatory disallowance of $3.7 million. On April 23, 2024, PNM filed an interim notice informing the NMPRC that PNM’s updated analysis indicates it is in the interest of customers for PNM to remain as a participant in Four Corners until the expiration of the current coal supply agreement in 2031. In August 2024, PNM and NTEC terminated the Four Corners Purchase and Sale Agreement and executed an agreement for the reimbursement of PNM’s initial $15.0 million payment with interest, which was paid in 2024.

2026 Resource Application

On October 25, 2023, PNM filed an application with the NMPRC seeking approval of resources to be available for the 2026 summer peak. The application included a request for approval of a 100 MW solar PPA and three ESAs of 100 MW, 100 MW, and 50 MW. In addition, PNM was seeking approval of a CCN for a 60 MW battery to be owned by PNM. The resources were deemed necessary for PNM to safely and reliably meet its projected system load. A hearing was held on March 20 and 21, 2024. On May 3, 2024, the hearing examiner in the case issued a RD approving PNM’s requested resources. On May 30, 2024, the NMPRC approved the RD in its entirety. On July 9, 2024, a group of New Mexico legislators filed a petition with the NM Supreme Court requesting the court grant their motion for rehearing, which was denied on September 3, 2024. This matter is now concluded.

2028 Resource Application

On November 22, 2024, PNM filed an application with the NMPRC seeking approval of ESAs, a PPA, and a CCN for system resources in 2028 to be available to meet summer 2028 customer needs. PNM is requesting approval of:

•Two 150 MW ESAs

•A 167 MW PPA for the Valencia power plant through 2039

•A CCN for a 100 MW solar facility and a 30 MW battery to be PNM-owned and located in San Juan County. The request provides the opportunity to increase the 30 MW battery by an additional 20 MW

A hearing will be held beginning April 2, 2025, if needed.

Grid Modernization Plan

On October 3, 2022, in compliance with New Mexico Grid Modernization Statute, PNM filed its Grid Modernization Application with the NMPRC. The projects included in the Grid Modernization Application improve customers’ ability to customize their use of energy and ensure that customers, including low-income customers, are a top priority and will benefit consistent with the Grid Modernization Statute. PNM’s proposal to modernize its electricity grid through infrastructure and technology improvements also increases the efficiency, reliability, resilience, and security of PNM’s electric system. PNM’s application seeks approval of grid modernization investments of approximately $344 million for the first six years of a broader 11-year strategy. The proposed Grid Modernization Rider would recover capital costs, operating expenses, and taxes associated

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December 31, 2024, 2023 and 2022

with the investments included in the Grid Modernization Application. PNM also requested authorization to create related regulatory assets and liabilities, permitting PNM to record costs incurred for the development and implementation of PNM’s plan between the requested approval of the application on July 1, 2023, and the implementation of the Grid Modernization Rider by September 1, 2023; undepreciated investments associated with legacy meters being replaced with AMI meters; and over- or under-collection of costs through the Grid Modernization Rider. In addition, PNM requested approval of the proposed format of an Opt-Out Consent Form and proposed opt-out fees, which includes a one-time fee and a monthly fee. Following a hearing and subsequent briefs, on May 31, 2023, the NMPRC issued an order requiring the hearing examiner to direct PNM to file a cost benefit analysis as a supplement to the application. On November 22, 2023, PNM filed the required cost benefit analysis supporting PNM’s proposed Grid Modernization plan. A hearing was held in April 2024 and post-hearing briefs and response briefs were filed in June 2024. On August 16, 2024, the hearing examiner in the case issued a RD. The RD largely approved PNM’s application with minor modifications, including limiting to a return of its undepreciated costs of legacy meters and conditioned approval upon PNM accelerating the deployment schedule following a final order. On October 17, 2024, the NMPRC issued a final order adopting the RD but removed the accelerated deployment schedule.

The Community Solar Act

In 2021, the Community Solar Act established a program that allows for the development of community solar facilities and provides customers of a qualifying utility with the option of subscribing to community solar facilities, and in exchange would receive a bill credit from their utility, while the utility received energy from the community solar facility. The NMPRC was charged with administering the Community Solar Act program, establishing a total maximum capacity of 200 MW community solar facilities and allocating proportionally to the New Mexico electric investor-owned utilities and participating cooperatives, of which PNM was allocated 125 MW. On October 3, 2024, the NMPRC issued an order raising the total maximum capacity of community solar facilities by 300 MW, of which PNM was allocated 185 MW.

In 2022, PNM filed its initial Community Solar tariff and subsequently filed an updated Community Solar tariff under protest and filed a motion for clarification, suspension, and timely hearing on PNM’s Community Solar tariff. In 2023, the NMPRC suspended PNM’s Community Solar tariff and issued an order opening a new docket for two-phase proceedings. The first phase addressed issues concerning the proposed subscriber organization agreements and the proposed customer data forms. The second phase addressed all issues concerning proposed tariffs, agreements and forms that were not addressed in the first phase. In 2023, the NMPRC issued an order approving an uncontested stipulation on the first phase and PNM’s advice notice conforming to the stipulation became effective. A hearing for the second phase was held from January 17 through January 19, 2024. On August 30, 2024, the hearing examiner issued a RD, that recommended rejecting PNM’s proposed community solar rider and required PNM to refile the rider, approval of an accounting order to track certain costs in a regulatory asset and included recommendations for various issues to be handled in a future rulemaking. On November 26, 2024, the NMPRC issued an order rejecting substantially all tariffs, agreements and forms, requiring PNM to file new proposed tariffs, in addition to adopting a majority of other components proposed in the RD. PNM filed revised tariffs on February 21, 2025. PNM cannot predict the outcome of the pending matters.

FERC Compliance

PNM conducted a comprehensive internal review of its filings with FERC regarding the potential timely filing of certain agreements that contained deviations from PNM’s standard form of service agreement in its OATT and assessing any applicable FERC waivers or refund requirements. Upon completion of the comprehensive review, PNM identified service agreements containing provisions that do not conform to the standard form of agreement on file with FERC. On March 18 and March 21, 2022, PNM filed applications with FERC requesting acceptance of certain agreements as well as rejection of other service agreements and further requesting that FERC not assess time-value refunds on the accepted agreements. On May 17, 2022, FERC issued two delegated letter orders accepting the service agreements and requiring PNM to pay the time-value refunds on the revenues it received on unaffiliated, late-filed, service agreements which contained language alleged to be non-conforming.

On November 21, 2022, FERC issued an order on rehearing that required PNM to pay its customers approximately $8.1 million in time-value refunds. On November 28, 2022, PNM filed an unopposed motion for voluntary dismissal with the United States Court of Appeals for the District of Columbia of its petitions for review, which was granted on December 22, 2022. In the fourth quarter of 2022, PNM made payments totaling $8.1 million to customers which were recorded as a reduction to electric operating revenues on the Consolidated Statements of Earnings. This matter is now concluded.

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December 31, 2024, 2023 and 2022

FERC Order 864

In November 2019, FERC issued Order No. 864, which required public utility transmission providers with transmission formula rates to revise those rates to account for changes resulting from the Tax Cuts and Jobs Act of 2017 (the “Tax Act”). PNM had already made revisions to its formula rate to account for Tax Act changes, and, as a result of the Order, PNM proposed additional changes to its formula rate to implement the remaining requirements of the Order. In July 2022, FERC issued an order finding that PNM had predominantly complied with the requirements but set aside certain matters for settlement and hearing procedures.

On November 22, 2023, PNM, on behalf of the settling parties, filed a settlement agreement with FERC resolving all issues. As a result of the settlement agreement, PNM recorded a decrease of $3.2 million to electric operating revenues and an increase to interest charges of $0.3 million on the Consolidated Statement of Earnings and an increase to other current liabilities of $3.5 million on the Consolidated Balance Sheets as of and for the year ended December 31, 2023. This matter is now concluded.

Transportation and Electrification Program (TEP)

On June 1, 2023, PNM filed its 2024-2026 TEP with the NMPRC, requesting approval of a $37.1 million total three-year budget and continuation of the current TEP Rider. Approximately 22% of the budget, $8.0 million, will be dedicated to low-income customers. On February 2, 2024, the hearing examiners in the case issued a RD largely approving PNM’s 2024 Plan but with modifications to certain TEP programs. On February 23, 2024, the NMPRC approved the RD with additional modifications that reduced the three-year budget by $4.0 million, for a total revised budget of $32.9 million. The TEP rider became effective on April 26, 2024.

TNMP

Energy Efficiency

TNMP recovers the costs of its energy efficiency programs through an energy efficiency cost recovery factor (“EECRF”), which includes projected program costs, under or over collected costs from prior years, rate case expenses, and performance bonuses (if the programs exceed mandated savings goals).

The following sets forth TNMP’s EECRF increases:


Effective Date	Aggregate Collection Amount		Performance Bonus
	(In millions)






March 1, 2022	$	7.2	$	2.3
March 1, 2023	7.3		1.9
March 1, 2024	6.6		1.2

On May 31, 2024, TNMP filed its request to adjust the EECRF to reflect changes in costs for 2025. On October 24, 2024, the PUCT approved the total amount requested, authorizing recovery of $7.0 million, including a performance bonus of $1.3 million based on TNMP’s energy efficiency achievements in the 2023 plan year.

Transmission Cost of Service Rates

TNMP can update its TCOS rates twice per year to reflect changes in its invested capital although updates are not allowed while a general rate case is in process. Updated rates reflect the addition and retirement of transmission facilities, including appropriate depreciation, federal income tax and other associated taxes, and the approved rate of return on such facilities.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The following sets forth TNMP’s recent interim transmission cost rate increases:


Effective Date	Approved Increase in Rate Base		Annual Increase in Revenue
	(In millions)














March 25, 2022	$	95.6	$	14.2
September 22, 2022	36.0		5.3
May 12, 2023	150.5		19.4
September 6, 2023	21.4		4.2
March 15, 2024	97.4		13.1
September 20, 2024	20.6		3.9

On January 24, 2025, TNMP filed an application to further update its transmission rates, which would increase revenues by $11.5 million annually, based on an increase in rate base of $83.5 million. The application is pending before the PUCT.

Periodic Distribution Rate Adjustment

PUCT rules permit interim rate adjustments to reflect changes in investments in distribution assets. Historically, distribution utilities have been restricted to a single, annual periodic rate adjustment through a DCRF submitted between April 1 and April 8 of each year as long as the electric utility was not earning more than its authorized rate of return using weather-normalized data. However, the recent passage of Senate Bill 1015 now permits DCRF proceedings to be filed twice per year with a 60-day administrative deadline that can be extended for 15 days on good cause. Additionally, a DCRF may be filed during a pending rate case proceeding as long as that DCRF request is not filed until the 185th day after the rate case proceeding was initiated. The following sets forth TNMP’s recent interim distribution rate increases:


Effective Date	Approved Increase in Rate Base		Annual Increase in Revenue
	(In millions)















September 1, 2022	$	95.7	$	6.8
September 1, 2023	157.0		14.5
July 28, 2024	205.9		15.6
November 17, 2024	43.7		7.7

3G Meters Notice of Violation

In 2020, the PUCT established the COVID-19 Electricity Relief Program for electric utilities, REPs, and customers impacted by COVID-19. The program allowed providers to implement a rider to collect unpaid residential retail customer bills and to establish a regulatory asset for costs related to COVID-19. These costs included but were not limited to costs related to unpaid accounts.

In December 2023, TNMP and the PUCT reached a settlement agreement related to a notice of violation against TNMP primarily for estimating 3G meters during the period that TNMP was remediating the meters. TNMP maintained that the remediation efforts were impacted by supply chain and labor availability issues resulting from COVID-19. Pursuant to the settlement agreement, TNMP agreed to no longer pursue the recovery of COVID-19 related costs that were recorded as a regulatory asset. This resulted in a regulatory disallowance of $1.2 million recorded for the year ended December 31, 2023.

Hurricane Beryl

On July 8, 2024, Hurricane Beryl made landfall in the Texas Gulf Coast leaving approximately 116,000 customers in the TNMP service area without power. As of December 31, 2024, TNMP incurred $53.1 million of costs, of which $32.1 million has been recorded in Utility Plant and $21.0 million has been recorded as a regulatory asset. TNMP will continue to track storm-related restoration costs to seek collection of such costs in a future regulatory proceeding.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

System Resiliency Plan (“SRP”)

In 2023, the Texas Legislature enacted House Bill No, 2555 (“HB 2555”), permitting an electric utility to seek approval of, and cost recovery for, a system resiliency plan. On August 28, 2024, TNMP filed its first SRP with the PUCT designed to benefit customers through enhanced resiliency of its distribution system, as intended under HB 2555. The SRP includes approximately $600 million of capital investments and approximately $151 million of other related costs over three years and was developed using a comprehensive and data-driven approach which evaluated various types of resiliency events posing material risk to the safe and reliable operation of TNMP's distribution system. TNMP's service territory includes non-contiguous areas across different regions of Texas, ranging from small communities and rural areas to communities around large metropolitan areas, each with unique risks. Investments in the SRP are prioritized based on customer benefit, physical protection of infrastructure, foundational investments in operational and cybersecurity technologies, and wildfire risk reduction and are focused on lower-performing areas in the context of reliability. Eight different resiliency measures are outlined in the SRP with associated programs and infrastructure impacts to improve the system's ability to prevent, withstand, mitigate and/or more promptly recover from resiliency events: distribution system resiliency, distribution system protection modernization, vegetation management, wildfire mitigation, flood mitigation, enhanced operations system technology, cybersecurity, and physical security resiliency. The SRP is subject to PUCT approval over 180 days as stated in Texas legislation. Recovery of investments and costs are permissible primarily through semi-annual DCRF filings, with deferral of depreciation and other certain expenses until recovery begins.

On December 11, 2024, TNMP filed an unopposed settlement with the PUCT. The settlement includes $565.8 million of capital investments over 2025 through 2027, reflecting 94% of TNMP’s proposed plan investments. The settlement also encompasses $128.2 million of operations and maintenance expenses associated with several programs, including vegetation management and wildfire mitigation.

(18)Income Taxes

Federal Income Tax Reform

In 2017, comprehensive changes in U.S. federal income taxes were enacted through legislation commonly known as the Tax Cuts and Jobs Act (the “Tax Act”). The Tax Act made many significant modifications to the tax laws, including reducing the federal corporate income tax rate from 35% to 21% effective January 1, 2018. The Tax Act also eliminated federal bonus depreciation for utilities, limited interest deductibility for non-utility businesses and limited the deductibility of officer compensation. During 2020, the IRS issued final regulations related to certain officer compensation and, in January 2021, issued final regulations on interest deductibility that provide a 10% “de minimis” exception that allows entities with predominantly regulated activities to fully deduct interest expenses.

As a result of the change in the federal income tax rate, the Company re-measured and adjusted its deferred tax assets and liabilities as of December 31, 2017. The portion of that adjustment not related to PNM’s and TNMP’s regulated activities was recorded as a reduction in net deferred tax assets and an increase in income tax expense. The portion related to PNM’s and TNMP’s regulated activities was recorded as a reduction in net deferred tax liabilities and an increase in regulatory liabilities.

Beginning February 2018, PNM’s NM 2016 Rate Case reflected the reduction in the federal and state corporate income tax rates, including amortization of excess deferred federal and state income taxes. In accordance with the order in that case and amortization requirements of the tax laws, PNM is returning the protected portion of excess deferred federal income taxes to customers over the average remaining life of plant in service as of December 31, 2017. The remaining balance of the unprotected portion of excess deferred federal income taxes, which was being returned to customers over a period of approximately twenty-three years, will be returned over a five-year period when new rates go into effect from the 2024 Rate Change. Excess deferred state income taxes were returned to customers over a three-year period, which concluded in the first quarter of 2021. The approved settlement in the TNMP 2018 Rate Case includes a reduction in customer rates to reflect the impacts of the Tax Act beginning on January 1, 2019. TXNM, PNM, and TNMP amortized federal excess deferred income taxes of $23.4 million, $20.8 million, and $2.6 million in 2024.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

TXNM

TXNM’s income taxes (benefits) consist of the following components:


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Current federal income tax	$	—	$	—	$	—
Current state income tax (benefit)	(1,984)		(2,841)		1,597
Deferred federal income tax (benefit)	13,042		(11,503)		18,413
Deferred state income tax (benefit)	10,630		(825)		7,302

Amortization of accumulated investment tax credits	(170)		(1,181)		(1,182)
Total income taxes (benefits)	$	21,518	$	(16,350)	$	26,130

TXNM’s provision for income taxes (benefits) differed from the federal income tax computed at the statutory rate for each of the years shown. The differences are attributable to the following factors:


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Federal income tax at statutory rates	$	58,850	$	19,011	$	44,375
Amortization of accumulated investment tax credits	(170)		(1,181)		(1,182)
Amortization of excess deferred income tax	(23,362)		(22,859)		(23,599)
Flow-through of depreciation items	1,003		1,281		2,795
(Earnings) attributable to non-controlling interest in Valencia	(3,368)		(3,892)		(3,176)
State income tax (benefit), net of federal (benefit)	6,284		(2,239)		6,826

Allowance for equity funds used during construction	(3,756)		(3,145)		(2,898)



Allocation of tax (benefit) related to stock compensation awards	(17)		(261)		91
Non-deductible compensation	1,332		1,659		1,125
Non-deductible merger related costs	—		(1,959)		74
Sale of NMRD	(15,822)		—		—
R&D credit	(1,500)		(2,050)		(1,320)
Other	2,044		(715)		3,019
Total income taxes (benefits)	$	21,518	$	(16,350)	$	26,130


Effective tax rate			7.68		%				(18.06)		%				12.37		%

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The components of TXNM’s net accumulated deferred income tax liability were:


	December 31,
	2024		2023
	(In thousands)
Deferred tax assets:
Net operating loss	$	31,592	$	16,833

Regulatory liabilities related to income taxes	82,702		90,461
Federal tax credit carryforwards	126,770		124,510

Regulatory disallowances	42,330		42,330
Regulatory liability SJGS retirement credits	40		28,797
Other	52,955		35,492
Total deferred tax assets	336,389		338,423
Deferred tax liabilities:
Depreciation and plant related	(794,203)		(738,078)
Investment tax credit	(81,068)		(95,046)
Regulatory assets related to income taxes	(84,053)		(80,643)

Pension	(41,383)		(41,141)
Regulatory asset for shutdown of SJGS Units 2 and 3	(20,860)		(22,454)

Regulatory asset SJGS energy transition property	(85,365)		(86,521)
Regulatory asset PVNGS investment	(21,044)		(20,503)
PVNGS trusts	(48,421)		(41,767)
Other	(59,384)		(57,550)
Total deferred tax liabilities	(1,235,781)		(1,183,703)
Net accumulated deferred income tax liabilities	$	(899,392)	$	(845,280)

The following table reconciles the change in TXNM’s net accumulated deferred income tax liability to the deferred income tax (benefit) included in the Consolidated Statement of Earnings:


	Year Ended
	December 31, 2024
	(In thousands)
Net change in deferred income tax liability per above table	$	54,112
Change in tax effects of income tax related regulatory assets and liabilities	(11,629)
Amortization of excess deferred income tax	(23,362)
Tax effect of mark-to-market adjustments	4,802
Tax effect of excess pension liability	(421)
Adjustment for uncertain income tax positions	(135)
Reclassification of unrecognized tax benefits	135




Other	—
Deferred income tax (benefit)	$	23,502

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

PNM

PNM’s income taxes (benefits) consist of the following components:


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Current federal income tax (benefit)	$	(7,005)	$	9,518	$	(13,533)
Current state income tax (benefit)	(5,681)		(4,304)		3,244
Deferred federal income tax (benefit)	28,183		(22,951)		25,298
Deferred state income tax	13,890		1,150		4,361

Amortization of accumulated investment tax credits	(170)		(171)		(172)
Total income taxes (benefits)	$	29,217	$	(16,758)	$	19,198

PNM’s provision for income taxes (benefits) differed from the federal income tax computed at the statutory rate for each of the years shown. The differences are attributable to the following factors:


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Federal income tax at statutory rates	$	49,868	$	7,972	$	29,026
Amortization of accumulated investment tax credits	(170)		(171)		(172)
Amortization of excess deferred income tax	(20,750)		(14,252)		(14,421)
Flow-through of depreciation items	796		1,114		2,641
(Earnings) attributable to non-controlling interest in Valencia	(3,368)		(3,892)		(3,176)
State income tax (benefit), net of federal (benefit)	6,594		(2,216)		5,694

Allowance for equity funds used during construction	(2,739)		(2,065)		(1,958)




Allocation of tax (benefit) related to stock compensation awards	(10)		(185)		65
Non-deductible compensation	822		1,015		701
Non-deductible merger costs	—		(33)		10
R&D credit	(1,450)		(2,000)		(1,300)
Other	(376)		(2,045)		2,088
Total income taxes (benefits)	$	29,217	$	(16,758)	$	19,198


Effective tax rate			12.30		%				(44.15)		%				13.89		%

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

The components of PNM’s net accumulated deferred income tax liability were:


	December 31,
	2024		2023
	(In thousands)
Deferred tax assets:
Net operating loss	$	—	$	—

Regulatory liabilities related to income taxes	64,481		71,546
Federal tax credit carryforwards	93,481		80,586

Regulatory disallowance	42,330		42,330
Regulatory liability SJGS retirement credits	40		28,797
Other	35,650		35,993
Total deferred tax assets	235,982		259,252
Deferred tax liabilities:
Depreciation and plant related	(582,089)		(545,815)
Investment tax credit	(81,068)		(73,844)
Regulatory assets related to income taxes	(75,464)		(71,742)
Pension	(36,678)		(36,483)
Regulatory asset for shutdown of SJGS Units 2 and 3	(20,860)		(22,454)

Regulatory asset SJGS energy transition property	(85,365)		(86,521)
Regulatory asset PVNGS investment	(21,044)		(20,503)
PVNGS Trusts	(48,421)		(41,767)
Other	(41,211)		(44,160)
Total deferred tax liabilities	(992,200)		(943,289)
Net accumulated deferred income tax liabilities	$	(756,218)	$	(684,037)

The following table reconciles the change in PNM’s net accumulated deferred income tax liability to the deferred income tax (benefit) included in the Consolidated Statement of Earnings:


	Year Ended
	December 31, 2024
	(In thousands)
Net change in deferred income tax liability per above table	$	72,181
Change in tax effects of income tax related regulatory assets and liabilities	(11,246)
Amortization of excess deferred income tax	(20,750)
Tax effect of mark-to-market adjustments	3,554
Tax effect of excess pension liability	(421)
Adjustment for uncertain income tax positions	(161)
Reclassification of unrecognized tax benefits	(1,254)





Deferred income tax (benefit)	$	41,903

TNMP

TNMP’s income taxes consist of the following components:


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Current federal income tax	$	(2,549)	$	11,354	$	17,055
Current state income tax	3,300		3,055		2,662
Deferred federal income tax (benefit)	26,363		2,917		(4,527)
Deferred state income tax (benefit)	—		(29)		(29)
Total income taxes	$	27,114	$	17,297	$	15,161

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

TNMP’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the periods shown. The differences are attributable to the following factors:


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Federal income tax at statutory rates	$	27,435	$	23,569	$	22,560
Amortization of excess deferred income tax	(2,612)		(8,607)		(9,177)
State income tax, net of federal (benefit)	2,606		2,414		2,103

Allocation of tax (benefit) related to stock compensation awards	(4)		(77)		26
Non-deductible compensation	509		642		422
Transaction costs	—		3		1
Other	(820)		(647)		(774)
Total income taxes	$	27,114	$	17,297	$	15,161


Effective tax rate			20.75		%				15.41		%				14.11		%

The components of TNMP’s net accumulated deferred income tax liability were:


	December 31,
	2024		2023
	(In thousands)
Deferred tax assets:
Regulatory liabilities related to income taxes	$	18,221	$	18,915
Other	4,522		5,534
Total deferred tax assets	22,743		24,449
Deferred tax liabilities:
Depreciation and plant related	(200,709)		(179,483)

Regulatory assets related to income taxes	(8,589)		(8,901)
Loss on reacquired debt	(4,981)		(5,254)
Pension	(4,706)		(4,659)
AMS	(2,709)		(2,613)
Other	(9,156)		(2,287)
Total deferred tax liabilities	(230,850)		(203,197)
Net accumulated deferred income tax liabilities	$	(208,107)	$	(178,748)

The following table reconciles the change in TNMP’s net accumulated deferred income tax liability to the deferred income tax included in the Consolidated Statement of Earnings:


	Year Ended
	December 31, 2024
	(In thousands)
Net change in deferred income tax liability per above table	$	29,359
Change in tax effects of income tax related regulatory assets and liabilities	(383)
Amortization of excess deferred income tax	(2,612)
Other	(1)
Deferred income tax	$	26,363

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Other Disclosures

The Company is required to recognize only the impact of tax positions that, based on their technical merits, are more likely than not to be sustained upon an audit by the taxing authority. A reconciliation of unrecognized tax benefits is as follows:


	TXNM		PNM		TNMP
	(In thousands)
Balance at December 31, 2021	$	13,714	$	10,771	$	141
Additions based on tax positions related to 2021	1,444		1,437		7
Additions (reductions) for tax positions of prior years	(4)		(7)		3

Balance at December 31, 2022	15,154		12,201		151
Additions based on tax positions related to 2022	(277)		(294)		17
Additions (reductions) for tax positions of prior years	259		239		20

Balance at December 31, 2023	15,136		12,146		188
Additions (reductions) based on tax positions related to 2023	19		2		17
Additions for tax positions of prior years	(154)		(163)		9

Balance at December 31, 2024	$	15,001	$	11,985	$	214

Included in the balance of unrecognized tax benefits at December 31, 2024 are $14.9 million, $11.9 million, and $0.2 million that, if recognized, would affect the effective tax rate for TXNM, PNM, and TNMP. The Company does not anticipate that any unrecognized tax expenses or unrecognized tax benefits will be reduced or settled in 2025.

TXNM, PNM, and TNMP had no estimated interest income or expense related to income taxes for the years ended December 31, 2024, 2023, and 2022. There was no accumulated accrued interest receivable or payable related to income taxes as of December 31, 2024 and 2023.

The Company files a federal consolidated and several consolidated and separate state income tax returns. The tax years prior to 2021 are closed to examination by either federal or state taxing authorities other than Arizona. The tax years prior to 2020 are closed to examination by Arizona taxing authorities. Other tax years are open to examination by federal and state taxing authorities and net operating loss carryforwards are open to examination for the years in which the carryforwards are utilized. At December 31, 2024, the Company has $186.2 million of federal net operating loss carryforwards that expire beginning in 2036 and $129.0 million of federal tax credit carryforwards that expire beginning in 2025. State net operating losses expire beginning in 2037 and vary from federal due to differences between state and federal tax law.

In 2008, fifty percent bonus tax depreciation was enacted as a temporary two-year stimulus measure as part of the Economic Stimulus Act of 2008. Bonus tax depreciation in various forms has been extended since that time, including by the Protecting Americans from Tax Hikes Act of 2015. The 2015 act extended and phased-out bonus tax depreciation through 2019. As discussed above, the Tax Act eliminated bonus depreciation for utilities effective September 28, 2017. However, in 2020 the IRS issued regulations interpreting Tax Act amendments to depreciation provisions of the IRC which allowed the Company to claim a bonus depreciation deduction on certain construction projects placed in service after the third quarter of 2017. As a result of the net operating loss carryforwards for income tax purposes created by bonus depreciation, certain tax carryforwards were not expected to be utilized before their expiration. In addition, as a result of Tax Act changes to the deductibility of officer compensation, certain deferred tax benefits related to compensation are not expected to be realized. The Company has impaired the deferred tax assets for tax carryforwards which are not expected to be utilized and for compensation that is not expected to be deductible.

The Company earns investment tax credits for construction or purchase of eligible property. The Company uses the deferral method of accounting for these investment tax credits.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

Impairments of tax attributes after reflecting the expiration of carryforwards under applicable tax laws, net of federal tax benefit, for 2022 through 2024 are as follows:


	TXNM		PNM		TNMP
	(In thousands)





December 31, 2024:
Federal tax credit carryforwards	$	131	$	—	$	—


Compensation expense	$	(516)	$	(335)	$	(179)
December 31, 2023:
Federal tax credit carryforwards	$	839	$	(427)	$	—


Compensation expense	$	387	$	246	$	140
December 31, 2022:
Federal tax credit carryforwards	$	187	$	427	$	—


Compensation expense	$	199	$	140	$	59

The tax effect of compensation that is not expected to be deductible and impairments of unexpired tax credits are reflected as a valuation allowance against deferred tax assets. The reserve balances, after reflecting expiration of carryforwards under applicable tax laws, at December 31, 2024 and 2023 are as follows:


	TXNM		PNM		TNMP
	(In thousands)
December 31, 2024:
Federal tax credit carryforwards	$	2,186	$	—	$	—


Compensation expense	$	596	$	394	$	202
December 31, 2023:
Federal tax credit carryforwards	$	2,055	$	—	$	—


Compensation expense	$	1,112	$	729	$	381

(19) Goodwill

The excess purchase price over the fair value of the assets acquired and the liabilities assumed by TXNM for its 2005 acquisition of TNP was recorded as goodwill and was pushed down to the businesses acquired. In 2007, the TNMP assets that were included in its New Mexico operations, including goodwill, were transferred to PNM. TXNM’s reporting units that currently have goodwill are PNM and TNMP.

The Company evaluates its goodwill for impairment annually at the reporting unit level or more frequently if circumstances indicate that the goodwill may be impaired. Application of the impairment test requires judgment, including the identification of reporting units, assignment of assets and liabilities to reporting units, and determination of the fair value of each reporting unit.

In certain circumstances an entity may perform a qualitative analysis to conclude that the goodwill of a reporting unit is not impaired. Under a qualitative assessment an entity considers macroeconomic conditions, industry and market considerations, cost factors, overall financial performance, other relevant entity-specific events affecting a reporting unit, as well as whether a sustained decrease (both absolute and relative to its peers) in share price has occurred. An entity considers the extent to which each of the adverse events and circumstances identified could affect the comparison of a reporting unit’s fair value with its carrying amount. An entity places more weight on the events and circumstances that most affect a reporting unit’s fair value or the carrying amount of its net assets. An entity also considers positive and mitigating events and circumstances that may affect its determination of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. An entity evaluates, on the basis of the weight of evidence, the significance of all identified events and circumstances in the context of determining whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. A quantitative analysis is not required if, after assessing events and circumstances, an entity determines that it is not more likely than not that the fair value of a reporting unit is less than its carrying amount.

In other circumstances, an entity may perform a quantitative analysis to reach the conclusion regarding impairment with respect to a reporting unit. An entity may choose to perform a quantitative analysis without performing a qualitative analysis

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

and may perform a qualitative analysis for certain reporting units, but a quantitative analysis for others. The first step of the quantitative impairment test requires an entity to compare the fair value of the reporting unit with its carrying value, including goodwill. If as a result of this analysis, the entity concludes there is an indication of impairment in a reporting unit having goodwill, the entity is required to perform the second step of the impairment analysis, determining the amount of goodwill impairment to be recorded. The amount is calculated by comparing the implied fair value of the goodwill to its carrying amount. This exercise would require the entity to allocate the fair value determined in step one to the individual assets and liabilities of the reporting unit. Any remaining fair value would be the implied fair value of goodwill on the testing date. To the extent the recorded amount of goodwill of a reporting unit exceeds the implied fair value determined in step two, an impairment loss would be reflected in results of operations.

TXNM periodically updates its quantitative analysis for both PNM and TNMP. The use of a quantitative approach in a given period is not necessarily an indication that a potential impairment has been identified under a qualitative approach. When TXNM performs a quantitative analysis for PNM or TNMP, a discounted cash flow methodology is primarily used to estimate the fair value of the reporting unit. This analysis requires significant judgments, including estimations of future cash flows, which is dependent on internal forecasts, estimations of long-term growth rates for the business, and determination of appropriate weighted average cost of capital for the reporting unit. Changes in these estimates and assumptions could materially affect the determination of fair value and the conclusion of impairment.

When TXNM performs a qualitative or quantitative analysis for PNM or TNMP, TXNM considers market and macroeconomic factors including changes in growth rates, changes in the WACC, and changes in discount rates. TXNM also evaluates its stock price relative to historical performance, industry peers, and to major market indices, including an evaluation of TXNM’s market capitalization relative to the carrying value of its reporting units.

For its annual evaluations performed as of April 1, 2022, TXNM performed a qualitative analysis for both the PNM and TNMP reporting units. In addition to the typical considerations discussed above, the qualitative analysis considered changes in the Company’s expectations of future financial performance since the April 1, 2018 quantitative analysis and the previous qualitative analyses through April 1, 2021 performed for PNM, as well as the April 1, 2020 quantitative analysis and the previous qualitative analyses performed for TNMP. This analysis considered Company specific events such as the Merger, potential impacts of legal and regulatory matters discussed in Notes 16 and 17, including potential outcomes in PNM’s 2024 Rate Change, PNM’s San Juan Abandonment Application, PNM’s Four Corners Abandonment Application, PNM’s PVNGS Leased Interest Abandonment Application and other potential impacts of changes in PNM’s resource needs based on PNM’s 2020 IRP. Based on an evaluation of these and other factors, the Company determined it was not more likely than not that the April 1, 2022 carrying values of PNM and TNMP exceeded their fair value.

For its annual evaluations performed as of April 1, 2023, TXNM performed a qualitative analysis for both the PNM and TNMP reporting units. In addition to the typical considerations discussed above, the qualitative analysis considered changes in the Company’s expectations of future financial performance since the April 1, 2018 quantitative analysis and the previous qualitative analyses through April 1, 2022 performed for PNM, as well as the April 1, 2021 quantitative analysis and the previous qualitative analyses performed for TNMP. This analysis considered Company specific events such as the Merger, potential impacts of legal and regulatory matters discussed in Notes 16 and 17, including potential outcomes in PNM’s 2024 Rate Change, PNM’s San Juan Abandonment Application, PNM’s Four Corners Abandonment Application, PNM’s PVNGS Leased Interest Abandonment Application and other potential impacts of changes in PNM’s resource needs based on PNM’s 2020 IRP. Based on an evaluation of these and other factors, the Company determined it was not more likely than not that the April 1, 2023 carrying values of PNM and TNMP exceeded their fair value.

For its annual evaluations performed as of April 1, 2024, TXNM performed a quantitative analysis for the PNM reporting unit and a qualitative analysis for the TNMP reporting unit. The quantitative analysis, discussed above, indicated that the fair value of the PNM reporting unit, which has goodwill of $51.6 million, exceeded its carrying value by approximately 54%. The qualitative analysis, in addition to the typical considerations discussed above, considered changes in the Company’s expectations of future financial performance since the April 1, 2020 quantitative analysis and the previous qualitative analyses through April 1, 2023 performed for TNMP. This analysis considered events specific to TNMP such as the potential impacts of legal and regulatory matters discussed in Note 16 and Note 17. Based on an evaluation of these and other factors, the Company determined it was not more likely than not that the April 1, 2024 carrying values of PNM and TNMP exceeded their fair value. Since the April 1, 2024 annual evaluation, there have been no events or indications that the fair values of the reporting units with recorded goodwill have decreased below their carrying values.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

(20)Related Party Transactions

TXNM, PNM, TNMP, and NMRD are considered related parties, as is PNMR Services Company, a wholly-owned subsidiary of TXNM that provides corporate services to TXNM and its subsidiaries in accordance with shared services agreements. These services are billed at cost on a monthly basis to the business units. In addition, PNM purchases renewable energy from certain NMRD-owned facilities at a fixed price per MWh of energy produced. On February 27, 2024, PNMR Development and AEP OnSite Partners sold their respective interests in NMRD, and the table below reflects transactions with NMRD prior to the sale.

TXNM files a consolidated federal income tax return with its affiliated companies. A tax allocation agreement exists between TXNM and each of its affiliated companies. These agreements provide that the subsidiary company will compute its taxable income on a stand-alone basis. If the result is a net tax liability, such amount shall be paid to TXNM. If there are net operating losses and/or tax credits, the subsidiary shall receive payment for the tax savings from TXNM to the extent that TXNM is able to utilize those benefits.

See Note 7 for information on intercompany borrowing arrangements. The table below summarizes the nature and amount of related party transactions of TXNM, PNM and TNMP:


	Year Ended December 31,
	2024		2023		2022
			(In thousands)


Services billings:
TXNM to PNM	$	132,209	$	124,321	$	115,415
TXNM to TNMP	53,166		47,470		42,293
PNM to TNMP	440		349		411
TNMP to TXNM	114		141		141
TNMP to PNM	497		—		—


TXNM to NMRD	66		333		308
Renewable energy purchases:
PNM from NMRD	1,523		12,717		11,795





Interest billings:
TXNM to PNM	142		23		13
PNM to TXNM	612		582		249
TXNM to TNMP	210		129		166
Income tax sharing payments:

TXNM to PNM	2,351		5,338		—
PNM to TXNM	—		—		11,602
TNMP to TXNM	10,312		15,749		8,341

(21) Equity Method Investment

In September 2017, PNMR Development and AEP OnSite Partners created NMRD to pursue the acquisition, development, and ownership of renewable energy generation projects, primarily in the state of New Mexico. PNMR Development and AEP OnSite Partners each had a 50% ownership interest in NMRD.

On December 22, 2023, PNMR Development and AEP Onsite reached agreement with Exus New Mexico, LLC, a subsidiary of Exus North America Holdings, LLC, for the sale of NMRD and its subsidiaries, pursuant to a Membership Interest Purchase Agreement, dated December 22, 2023 (“MIPA”). Closing occurred on February 27, 2024, with PNMR Development receiving net proceeds of $117.0 million and recognized an after-tax gain of $4.4 million, which includes the recognition of deferred investment tax credits of $15.7 million.

TXNM accounted for its investment in NMRD using the equity method of accounting because TXNM’s ownership interest results in significant influence, but not control, over NMRD and its operations. TXNM recorded as income its percentage share of earnings or loss of NMRD and carried its investment at cost, adjusted for its share of undistributed earnings or losses.

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TXNM ENERGY, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2024, 2023 and 2022

During 2024, 2023 and 2022 PNMR Development and AEP OnSite Partners each made cash contributions of $12.6 million, $26.3 million and zero to NMRD.

TXNM presented its share of net earnings from NMRD in other income on the Consolidated Statements of Earnings. Summarized financial information for NMRD is as follows:



	December 31,
	2024		2023		2022
	(In thousands)
Operating revenues	$	3,204	$	13,629	$	12,505
Operating expenses	3,378		8,228		9,591
Net earnings	$	(174)	$	5,401	$	2,914


	Financial Position
	December 31,
	2024		2023
	(In thousands)
Current assets	$	—	$	2,589
Net property, plant, and equipment	—		235,791
Non-current assets	—		1,849
Total assets	—		240,229
Current liabilities	—		730
Non-current liabilities	—		358
Owners’ equity	$	—	$	239,141

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SCHEDULE I

TXNM ENERGY, INC.

CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY

STATEMENTS OF EARNINGS


	Year ended December 31,
	2024		2023		2022
	(In thousands)
Operating Revenues	$	—	$	—	$	—
Operating Expenses	9,406		4,972		6,199
Operating (loss)	(9,406)		(4,972)		(6,199)
Other Income and Deductions:
Equity in earnings of subsidiaries	299,867		133,628		197,860
Other income	1,427		2,245		663

Net other income and (deductions)	301,294		135,873		198,523
Interest Charges	64,916		58,934		30,430
Earnings Before Income Taxes	226,972		71,967		161,894
Income Tax (Benefit)	(15,182)		(15,851)		(7,636)


Net Earnings	$	242,154	$	87,818	$	169,530

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SCHEDULE I

TXNM ENERGY, INC.

CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY

STATEMENTS OF CASH FLOWS


	Year Ended December 31,
	2024		2023		2022
	(In thousands)
Cash Flows From Operating Activities:














Net Cash Flows From Operating Activities	$	(36,927)	$	(31,368)	$	(10,261)
Cash Flows From Investing Activities:
Additions to non-utility plant	839		1,138		1,136
Investments in subsidiaries	(112,000)		(85,500)		(70,200)
Cash dividends from subsidiaries	153,000		—		153,500

Net cash flows from investing activities	41,839		(84,362)		84,436
Cash Flows From Financing Activities:

Short-term borrowings (repayments) -affiliate, net	21,100		(5,300)		(700)
Revolving credit facility borrowings	822,000		837,000		640,400
Revolving credit facility repayments	(797,400)		(777,100)		(685,900)
Long-term borrowings	550,000		500,000		100,000
Repayment of long-term debt	(539,000)		(500,000)		—
Issuance of common stock	98,601		198,177		—


Awards of common stock	(8,460)		(9,646)		(7,980)
Dividends paid	(139,811)		(126,177)		(119,311)
Other, net	(11,945)		(1,221)		(686)
Net cash flows from financing activities	(4,915)		115,733		(74,177)

Change in Cash and Cash Equivalents	(3)		3		(2)
Cash and Cash Equivalents at Beginning of Period	64		61		63
Cash and Cash Equivalents at End of Period	$	61	$	64	$	61

Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	71,917	$	47,122	$	29,904
Income taxes paid (refunded), net	$	(1,707)	$	350	$	(2,500)

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SCHEDULE I

TXNM ENERGY, INC.

CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY

BALANCE SHEETS


	December 31,
	2024		2023
	(In thousands)
Assets
Cash and cash equivalents	$	61	$	64
Intercompany receivables	—		55,575
Derivative instruments	—		7,172
Income taxes receivable	15,326		8,266
Other current assets	15		133
Total current assets	15,402		71,210
Property, plant and equipment, net of accumulated depreciation of $19,650 and $18,810	19,536		20,374

Investment in subsidiaries	3,625,611		3,345,400
Other long-term assets	48,312		44,628
Total long-term assets	3,693,459		3,410,402
	$	3,708,861	$	3,481,612
Liabilities and Stockholders’ Equity
Short-term debt	93,900		69,300
Short-term debt-affiliate	30,319		9,219
Current installments of long-term debt	50,967		—
Intercompany payables	1,999		—
Accrued interest and taxes	6,428		14,650
Dividends declared	36,757		34,953
Other current liabilities	571		184
Total current liabilities	220,941		128,306
Long-term debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	948,731		999,151
Other long-term liabilities	2,803		5,062
Total liabilities	1,172,475		1,132,519
Common stock (no par value; 200,000,000 and $120,000,000 shares authorized; issued and outstanding 92,659,335 and 90,200,384 shares)	1,724,444		1,624,823
Accumulated other comprehensive income (loss), net of income taxes	(75,708)		(62,840)
Retained earnings	887,650		787,110
Total common stockholders’ equity	2,536,386		2,349,093
	$	3,708,861	$	3,481,612

See Notes 7, 8, 11, and 16 for information regarding commitments, contingencies, and maturities of long-term debt.

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