10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended September 30, 2021

Name of Registrant, State of Incorporation, Address Of Principal Executive Offices, Telephone Number, Commission File No., IRS Employer Identification No.

PNM Resources, Inc.

(A New Mexico Corporation)

414 Silver Ave. SW

Albuquerque, New Mexico 87102-3289

Telephone Number - (505) 241-2700

Commission File No. - 001-32462

IRS Employer Identification No. - 85-0468296

Public Service Company of New Mexico

(A New Mexico Corporation)

414 Silver Ave. SW

Albuquerque, New Mexico 87102-3289

Telephone Number - (505) 241-2700

Commission File No. - 001-06986

IRS Employer Identification No. - 85-0019030

Texas-New Mexico Power Company

(A Texas Corporation)

577 N. Garden Ridge Blvd.

Lewisville, Texas 75067

Telephone Number - (972) 420-4189

Commission File No. - 002-97230

IRS Employer Identification No. - 75-0204070

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

Registrant	Title of each class	Trading Symbol(s)	Name of exchange on which registered
PNM Resources, Inc.	Common Stock, no par value	PNM	New York Stock Exchange

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

PNM Resources, Inc. (“PNMR”)	Yes	☑	No	☐
Public Service Company of New Mexico (“PNM”)	Yes	☑	No	☐
Texas-New Mexico Power Company (“TNMP”)	Yes	☐	No	☑

(NOTE: As a voluntary filer, not subject to the filing requirements, TNMP filed all reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months.)

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

PNMR	Yes	☑	No	☐
PNM	Yes	☑	No	☐
TNMP	Yes	☑	No	☐

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

	Large accelerated filer		Accelerated filer		Non-accelerated filer		Smaller reporting company		Emerging growth company
PNMR		☑		☐		☐		☐		☐
	Large accelerated filer		Accelerated filer		Non-accelerated filer		Smaller reporting company		Emerging growth company
PNM		☐		☐		☑		☐		☐
	Large accelerated filer		Accelerated filer		Non-accelerated filer		Smaller reporting company		Emerging growth company
TNMP		☐		☐		☑		☐		☐

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

Indicate by check mark whether any of the registrants is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐   No ☑

As of October 22, 2021, 85,834,874 shares of common stock, no par value per share, of PNMR were outstanding.

The total number of shares of common stock of PNM, no par value per share, outstanding as of October 22, 2021 was 39,117,799 all held by PNMR (and none held by non-affiliates).

The total number of shares of common stock of TNMP, $10 par value per share, outstanding as of October 22, 2021 was 6,358 all held indirectly by PNMR (and none held by non-affiliates).

PNM AND TNMP MEET THE CONDITIONS SET FORTH IN GENERAL INSTRUCTIONS (H) (1) (a) AND (b) OF FORM 10-Q AND ARE THEREFORE FILING THIS FORM WITH THE REDUCED DISCLOSURE FORMAT PURSUANT TO GENERAL INSTRUCTION (H) (2).

This combined Form 10-Q is separately filed by PNMR, PNM, and TNMP.  Information contained herein relating to any individual registrant is filed by such registrant on its own behalf.  Each registrant makes no representation as to information relating to the other registrants.  When this Form 10-Q is incorporated by reference into any filing with the SEC made by PNMR, PNM, or TNMP, as a registrant, the portions of this Form 10-Q that relate to each other registrant are not incorporated by reference therein.

2

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

INDEX

	Page No.
GLOSSARY	4
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)
PNM RESOURCES, INC. AND SUBSIDIARIES
Condensed Consolidated Statements of Earnings	8
Condensed Consolidated Statements of Comprehensive Income	9
Condensed Consolidated Statements of Cash Flows	10
Condensed Consolidated Balance Sheets	12
Condensed Consolidated Statements of Changes in Equity	14
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
Condensed Consolidated Statements of Earnings	15
Condensed Consolidated Statements of Comprehensive Income	16
Condensed Consolidated Statements of Cash Flows	17
Condensed Consolidated Balance Sheets	19
Condensed Consolidated Statements of Changes in Equity	21
TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES
Condensed Consolidated Statements of Earnings	22
Condensed Consolidated Statements of Cash Flows	23
Condensed Consolidated Balance Sheets	24
Condensed Consolidated Statements of Changes in Common Stockholder’s Equity	26
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS	27
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	83
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	118
ITEM 4. CONTROLS AND PROCEDURES	120
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS	121
ITEM 1A. RISK FACTORS	121
ITEM 6. EXHIBITS	121
SIGNATURE	123

3

GLOSSARY

Definitions:
2020 IRP	PNM’s 2020 IRP
ABCWUA	Albuquerque Bernalillo County Water Utility Authority
ACE Rule	Affordable Clean Energy Rule
AEP OnSite Partners	AEP OnSite Partners, LLC, a subsidiary of American Electric Power, Inc.
Afton	Afton Generating Station
AFUDC	Allowance for Funds Used During Construction
ALJ	Administrative Law Judge
AMI	Advanced Metering Infrastructure
AMS	Advanced Meter System
AOCI	Accumulated Other Comprehensive Income
APS	Arizona Public Service Company, the operator and a co-owner of PVNGS and Four Corners
ARO	Asset Retirement Obligation
ARP	Alternative Revenue Program
Avangrid	Avangrid, Inc., a New York corporation
BART	Best Available Retrofit Technology
Board	Board of Directors of PNMR
BSER	Best system of emission reduction technology
CAA	Clean Air Act
Carbon Pollution Standards	Carbon Pollution Standards established by the EPA on August 3, 2015
CARES Act	Coronavirus Aid, Relief, and Economic Security Act
CCAE	Coalition for Clean Affordable Energy
CCR	Coal Combustion Residuals
CFIUS	Committee on Foreign Investment in the United States
CFRE	Citizens for Fair Rates and the Environment
CIAC	Contributions in Aid of Construction
Clean Power Plan	Clean Power Plan established by the EPA on August 3,2015 and published on October 23, 2015
CO2	Carbon Dioxide
COVID-19	Novel coronavirus global pandemic
CSA	Coal Supply Agreement
CTC	Competition Transition Charge
DC Circuit	United States Court of Appeals for the District of Columbia Circuit
DCOS	TNMP’s applications for a distribution cost recovery factor
DOE	United States Department of Energy
DOI	United States Department of Interior
Effective Time	The time the Merger is consummated
EGU	Electric Generating Unit
EIM	California Independent System Operator Western Energy Imbalance Market
Energy Transition Charge	Rate rider established to collect non-bypassable customer charges for repayment of the Securitized Bonds
EPA	United States Environmental Protection Agency
ERCOT	Electric Reliability Council of Texas
ESG	Environmental, Social, and Governance principles
ETA	The New Mexico Energy Transition Act
EUEA	The New Mexico Efficient Use of Energy Act
Exchange Act	Securities Exchange Act of 1934
FCC	Federal Communications Commission
FERC	Federal Energy Regulatory Commission
Four Corners	Four Corners Power Plant
Four Corners Abandonment Application	PNM’s January 8, 2021 application for approval for the abandonment of Four Corners and issuance of a securitized financing order
Four Corners CSA	Four Corners’ coal supply contract with NTEC
Four Corners Purchase and Sale Agreement	PNM’s pending sale of its 13% ownership interest in Four Corners to NTEC
FPPAC	Fuel and Purchased Power Adjustment Clause
FTC	Federal Trade Commission

4

FTY	Future Test Year
GAAP	Generally Accepted Accounting Principles in the United States of America
GHG	Greenhouse Gas Emissions
GWh	Gigawatt hours
HSR	Hart-Scott Rodino Antitrust Improvement Act of 1976
Iberdrola	Iberdrola, S.A., a corporation organized under the laws of the Kingdom of Spain, and 81.5% owner of Avangrid
INDC	Intended Nationally Determined Contribution
IRC	Internal Revenue Code
IRP	Integrated Resource Plan
IRS	Internal Revenue Service
ISFSI	Independent Spent Fuel Storage Installation
Joint Applicants	PNM, PNMR, Merger Sub, Avangrid and Iberdrola, S.A.
kV	Kilovolt
KW	Kilowatt
KWh	Kilowatt Hour
La Joya Wind II	La Joya Wind Facility generating 140 MW of output that became operational in June 2021
Leased Interest	Leased capacity in PVNGS Unit 1 and Unit 2
LIBOR	London Interbank Offered Rate
Lightning Dock Geothermal	Lightning Dock geothermal power facility, also known as the Dale Burgett Geothermal Plant
MD&A	Management’s Discussion and Analysis of Financial Condition and Results of Operations
Merger	The merger of Merger Sub with and into PNMR pursuant to the Merger Agreement, with PNMR surviving the Merger as a direct, wholly-owned subsidiary of Avangrid
Merger Agreement	The Agreement and Plan of Merger, dated October 20, 2020, between PNMR, Avangrid and Merger Sub
Merger Sub	NM Green Holdings, Inc., a New Mexico corporation and wholly-owned subsidiary of Avangrid which will merge with and into PNMR at the effective time of the Merger (defined below)
Moody’s	Moody’s Investor Services, Inc.
MW	Megawatt
MWh	Megawatt Hour
NAAQS	National Ambient Air Quality Standards
Navajo Acts	Navajo Nation Air Pollution Prevention and Control Act, Navajo Nation Safe Drinking Water Act, and Navajo Nation Pesticide Act
NDT	Nuclear Decommissioning Trusts for PVNGS
NEE	New Energy Economy
NERC	North American Electric Reliability Corporation
New Mexico Wind	New Mexico Wind Energy Center
NM 2015 Rate Case	Request for a General Increase in Electric Rates Filed by PNM on August 27, 2015
NM 2016 Rate Case	Request for a General Increase in Electric Rates Filed by PNM on December 7, 2016
NM Capital	NM Capital Utility Corporation, an unregulated wholly-owned subsidiary of PNMR, now known as New Mexico PPA Corporation
NM District Court	United States District Court for the District of New Mexico
NM Supreme Court	New Mexico Supreme Court
NMAG	New Mexico Attorney General
NMED	New Mexico Environment Department
NMMMD	The Mining and Minerals Division of the New Mexico Energy, Minerals and Natural Resources Department
NMPRC	New Mexico Public Regulation Commission
NMRD	NM Renewable Development, LLC, owned 50% each by PNMR Development and AEP OnSite Partners, LLC
NOx	Nitrogen Oxides
NPDES	National Pollutant Discharge Elimination System
NRC	United States Nuclear Regulatory Commission
NSR	New Source Review
NTEC	Navajo Transitional Energy Company, LLC, an entity owned by the Navajo Nation
OATT	Open Access Transmission Tariff
OCI	Other Comprehensive Income
OPEB	Other Post-Employment Benefits
OSM	United States Office of Surface Mining Reclamation and Enforcement

5

Paris Agreement	A legally binding international treaty on climate change adopted on December 12, 2015
PCRBs	Pollution Control Revenue Bonds
PM	Particulate Matter
PNM	Public Service Company of New Mexico and Subsidiaries
PNM 2017 New Mexico Credit Facility	PNM’s $40.0 Million Unsecured Revolving Credit Facility
PNM 2019 $40.0 Million Term Loan	PNM’s $40.0 Million Unsecured Term Loan
PNM 2020 Fixed Rate PCRBs	PNM's $302.5 Million PCRBs purchased on July 22, 2020
PNM 2020 Note Purchase Agreement	PNM's Agreement for the sale of PNM's 2020 SUNs
PNM 2020 SUNs	PNM's $200.0 Million Senior Unsecured Notes issued on April 30, 2020
PNM 2020 Term Loan	PNM’s $250.0 million Unsecured Term Loan issued on April 15, 2020, of which $100.0 million was repaid on April 30, 2020
PNM 2021 Fixed Rate PCRBs	PNM's $100.3 million PCRBs remarketed on October 1, 2021
PNM 2021 Note Purchase Agreement	PNM's Agreement for the sale of PNM's 2021 SUNs
PNM 2021 SUNs	PNM’s $160.0 Million Senior Unsecured Notes issued on July 14, 2021
PNM 2021 Term Loan	PNM’s $75.0 Million 18-month Unsecured Term Loan that mature on December 18, 2022
PNM Floating Rate PCRBs	PNM's $100.3 million PCRBs remarketed on July 1, 2020
PNM Plans	PNM's qualified defined benefit pension plans, postretirement benefit plans providing medical and dental benefits, and executive retirement programs
PNM Revolving Credit Facility	PNM’s $400.0 Million Unsecured Revolving Credit Facility
PNM September 2021 SUNs	PNM's $150.0 Million Senior Unsecured Notes to be issued on or before December 30, 2021
PNMR	PNM Resources, Inc. and Subsidiaries
PNMR 2018 SUNs	PNMR’s $300.0 Million Senior Unsecured Notes issued on March 9, 2018
PNMR 2019 Term Loan	PNMR’s $150.0 Million Unsecured Term Loan
PNMR 2020 Forward Equity Sale Agreements	PNMR’s Block Equity Sale of 6.2 million Shares of PNMR Common Stock with Forward Sales Agreement
PNMR 2020 Term Loan	PNMR’s $150.0 million Unsecured Term Loan that matures on January 31, 2022
PNMR 2020 Delayed-Draw Term Loan	PNMR’s $300.0 million Unsecured Delayed-Draw Term Loan that matures on January 31, 2022
PNMR 2021 Delayed-Draw Term Loan	PNMR's $1.0 Billion Unsecured Delayed-Draw Term Loan that matures on May 18, 2023
PNMR Development	PNMR Development and Management Company, an unregulated wholly-owned subsidiary of PNMR
PNMR Development Revolving Credit Facility	PNMR Development’s $40.0 million Unsecured Revolving Credit Facility
PNMR Development Term Loan	PNMR Development’s $65.0 Million Unsecured Term Loan that matures on January 31, 2022
PNMR Revolving Credit Facility	PNMR’s $300.0 Million Unsecured Revolving Credit Facility
PPA	Power Purchase Agreement
PSD	Prevention of Significant Deterioration
PUCT	Public Utility Commission of Texas
PV	Photovoltaic
PVNGS	Palo Verde Nuclear Generating Station
PVNGS Leased Interest Abandonment Application	Application with the NMPRC requesting approval for the decertification and abandonment of 114MW of leased PVNGS capacity
RCT	Reasonable Cost Threshold

6

REA	New Mexico’s Renewable Energy Act of 2004
RECs	Renewable Energy Certificates
Red Mesa Wind	Red Mesa Wind Energy Center
REP	Retail Electricity Provider
RMC	Risk Management Committee
ROE	Return on Equity
RPS	Renewable Energy Portfolio Standard
S&P	Standard and Poor’s Ratings Services
SEC	United States Securities and Exchange Commission
Securitized Bonds	Energy transition bonds
SIP	State Implementation Plan
SJCC	San Juan Coal Company
SJGS	San Juan Generating Station
SJGS Abandonment Application	PNM’s July 1, 2019 consolidated application seeking NMPRC approval to retire PNM’s share of SJGS in 2022, for related replacement generating resources, and for the issuance of securitized bonds under the ETA
SJGS CSA	San Juan Generating Station Coal Supply Agreement
SJGS RA	San Juan Project Restructuring Agreement
SO2	Sulfur Dioxide
SRP	Salt River Project
Staff	NMPRC Staff
SUNs	Senior Unsecured Notes
Tax Act	Federal tax reform legislation enacted on December 22, 2017, commonly referred to as the Tax Cuts and Jobs Act
TECA	Texas Electric Choice Act
Tenth Circuit	United States Court of Appeals for the Tenth Circuit
TEP	Transportation Electrification Program
TNMP	Texas-New Mexico Power Company and Subsidiaries
TNMP 2018 Rate Case	TNMP's General Rate Case Application filed May 30, 2018
TNMP 2020 Bonds	TNMP's First Mortgage Bonds issued on April 24, 2020 under the TNMP 2020 Bond Purchase Agreement
TNMP 2020 Bond Purchase Agreement	TNMP's Agreement for the sale of TNMP's 2020 First Mortgage Bonds
TNMP 2021 Bonds	TNMP's First Mortgage Bonds to be issued under the TNMP 2021 Bond Purchase Agreement
TNMP 2021 Bond Purchase Agreement	TNMP's Agreement for the sale of TNMP's 2021 First Mortgage Bonds
TNMP FMBs	TNMP's aggregate $750.0 million of outstanding 2014 to 2020 First Mortgage Bonds
TNMP Plans	TNMP's qualified defined benefit pension plans, postretirement benefit plans providing medical and dental benefits, and executive retirement programs
TNMP Revolving Credit Facility	TNMP’s $75.0 Million Secured Revolving Credit Facility
TSAs	Transmission Service Agreements
U.S.	The Unites States of America
US Supreme Court	United States Supreme Court
Valencia	Valencia Energy Facility
VIE	Variable Interest Entity
WACC	Weighted Average Cost of Capital
Western Spirit Line	A 153-mile 345-kV transmission line that PNM has agreed to purchase, subject to certain conditions being met prior to closing
Westmoreland	Westmoreland Coal Company
WFB LOC Facility	Letter of credit arrangements with Wells Fargo Bank, N.A., entered into in August 2020
WRA	Western Resource Advocates
WSJ LLC	Westmoreland San Juan Mining, LLC, a subsidiary of Westmoreland Mining Holdings, LLC, and current owner of SJCC

7

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EARNINGS

(Unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands, except per share amounts)
Electric Operating Revenues:
Contracts with customers	$	481,881	$	455,120	$	1,197,359	$	1,121,177
Alternative revenue programs	(9,483)		(12,376)		(3,156)		(7,484)
Other electric operating revenue	82,153		29,721		151,595		50,043
Total electric operating revenues	554,551		472,465		1,345,798		1,163,736
Operating Expenses:
Cost of energy	199,380		133,991		467,452		326,564
Administrative and general	56,520		51,611		168,458		148,096
Energy production costs	32,374		31,148		106,709		98,111
Regulatory disallowances and restructuring costs	436		—		436		—
Depreciation and amortization	71,438		68,400		212,039		207,395
Transmission and distribution costs	19,996		18,742		56,166		54,062
Taxes other than income taxes	22,678		20,768		65,440		62,815
Total operating expenses	402,822		324,660		1,076,700		897,043
Operating income	151,729		147,805		269,098		266,693
Other Income and Deductions:
Interest income	3,329		3,180		10,466		9,674
Gains on investment securities	1,948		14,401		16,108		3,172
Other income	5,686		7,022		14,592		13,728
Other (deductions)	(5,098)		(7,361)		(13,836)		(14,141)
Net other income and deductions	5,865		17,242		27,330		12,433
Interest Charges	23,244		27,263		73,247		88,785
Earnings before Income Taxes	134,350		137,784		223,181		190,341
Income Taxes	16,668		12,331		26,533		14,726
Net Earnings	117,682		125,453		196,648		175,615
(Earnings) Attributable to Valencia Non-controlling Interest	(4,229)		(3,553)		(11,643)		(11,222)
Preferred Stock Dividend Requirements of Subsidiary	(132)		(132)		(396)		(396)
Net Earnings Attributable to PNMR	$	113,321	$	121,768	$	184,609	$	163,997
Net Earnings Attributable to PNMR per Common Share:
Basic	$	1.32	$	1.52	$	2.14	$	2.05
Diluted	$	1.32	$	1.52	$	2.14	$	2.05
Dividends Declared per Common Share	$	0.3275	$	0.3075	$	0.9825	$	0.9225

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

8

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands)
Net Earnings	$	117,682	$	125,453	$	196,648	$	175,615
Other Comprehensive Income:
Unrealized Gains on Available-for-Sale Debt Securities:
Net change in unrealized holding gains arising during the period, net of income tax (expense) benefit of $329, $(1,278), $246, and $(3,746)	(968)		3,755		(722)		11,004
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $632, $1,041, $2,062, and $1,818	(1,856)		(3,056)		(6,058)		(5,338)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience losses recognized as net periodic benefit cost, net of income tax (benefit) of $(530), $(527), $(1,590), and $(1,581)	1,557		1,548		4,671		4,644
Fair Value Adjustment for Cash Flow Hedges:
Change in fair market value, net of income tax (expense) of $0, $(313), $(458), and $(9)	—		918		1,346		24
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $0, $157, $229, and $284	—		(460)		(674)		(833)
Total Other Comprehensive Income (Loss)	(1,267)		2,705		(1,437)		9,501
Comprehensive Income	116,415		128,158		195,211		185,116
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(4,229)		(3,553)		(11,643)		(11,222)
Preferred Stock Dividend Requirements of Subsidiary	(132)		(132)		(396)		(396)
Comprehensive Income Attributable to PNMR	$	112,054	$	124,473	$	183,172	$	173,498

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

9

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine Months Ended September 30,
	2021		2020
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	196,648	$	175,615
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	238,963		233,537
Deferred income tax expense	25,293		13,804
(Gains) on investment securities	(16,108)		(3,172)
Stock based compensation expense	6,728		6,560
Regulatory disallowances and restructuring costs	436		—
Allowance for equity funds used during construction	(8,867)		(6,728)
Other, net	4,594		3,107
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(46,649)		(57,340)
Materials, supplies, and fuel stock	(333)		10,495
Other current assets	(20,005)		(9,885)
Other assets	17,551		22,608
Accounts payable	5,934		(8,116)
Accrued interest and taxes	7,713		(3,765)
Other current liabilities	17,679		16,755
Other liabilities	(21,065)		(25,518)
Net cash flows from operating activities	408,512		367,957
Cash Flows From Investing Activities:
Additions to utility plant and non-utility plant	(496,185)		(495,334)
Proceeds from sales of investment securities	396,870		489,218
Purchases of investment securities	(405,142)		(498,170)
Investments in NMRD	—		(23,250)
Distributions from NMRD	572		—
Other, net	108		166
Net cash flows used in investing activities	(503,777)		(527,370)

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

10

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine Months Ended September 30,
	2021		2020
	(In thousands)
Cash Flows From Financing Activities:
Short-term borrowings, net	$	—	$	494
Revolving credit facilities borrowings, net	(18,100)		(1,300)
Long-term borrowings	1,370,000		1,037,845
Repayment of long-term debt	(1,165,000)		(752,845)
Proceeds from stock option exercise	—		24
Awards of common stock	(10,082)		(11,984)
Dividends paid	(84,729)		(73,876)
Valencia’s transactions with its owner	(14,238)		(14,995)
Transmission interconnection and security deposit arrangements	31,878		8,614
Refunds paid under transmission interconnection arrangements	(9,752)		(4,400)
Debt issuance costs and other, net	(3,159)		(1,104)
Net cash flows from financing activities	96,818		186,473
Change in Cash, Restricted Cash, and Equivalents	1,553		27,060
Cash, Restricted Cash, and Equivalents at Beginning of Period	47,928		3,833
Cash, Restricted Cash, and Equivalents at End of Period	$	49,481	$	30,893
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	69,965	$	84,139
Income taxes paid (refunded), net	$	892	$	969
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	$	63,281	$	10,318

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

11

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2021		December 31, 2020
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	49,481	$	47,928
Accounts receivable, net of allowance for credit losses of $11,237 and $8,333	140,826		113,410
Unbilled revenues	64,874		55,504
Other receivables	28,788		23,797
Materials, supplies, and fuel stock	66,750		66,417
Regulatory assets	34,187		202
Income taxes receivable	5,323		5,672
Other current assets	57,484		64,549
Total current assets	447,713		377,479
Other Property and Investments:
Investment securities	455,409		440,115
Equity investment in NMRD	89,065		90,655
Other investments	148		284
Non-utility property, net	25,547		24,075
Total other property and investments	570,169		555,129
Utility Plant:
Plant in service, held for future use, and to be abandoned	8,723,398		8,480,799
Less accumulated depreciation and amortization	2,951,721		2,835,170
	5,771,677		5,645,629
Construction work in progress	350,090		218,719
Nuclear fuel, net of accumulated amortization of $48,062 and $41,367	97,055		100,801
Net utility plant	6,218,822		5,965,149
Deferred Charges and Other Assets:
Regulatory assets	544,432		557,790
Goodwill	278,297		278,297
Operating lease right-of-use assets, net of accumulated amortization	85,956		105,133
Other deferred charges	110,681		100,877
Total deferred charges and other assets	1,019,366		1,042,097
	$	8,256,070	$	7,939,854

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

12

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2021		December 31, 2020
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Short-term debt	$	13,900	$	32,000
Current installments of long-term debt	104,258		575,518
Accounts payable	111,970		169,317
Customer deposits	4,876		6,606
Accrued interest and taxes	75,571		68,206
Regulatory liabilities	13,381		7,471
Operating lease liabilities	28,230		27,460
Dividends declared	28,243		28,243
Transmission interconnection arrangement liabilities	30,983		6,883
Other current liabilities	63,795		55,958
Total current liabilities	475,207		977,662
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	3,395,975		2,719,632
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	744,856		694,512
Regulatory liabilities	855,855		850,228
Asset retirement obligations	192,132		183,421
Accrued pension liability and postretirement benefit cost	46,857		58,101
Operating lease liabilities	55,106		81,065
Other deferred credits	277,189		255,230
Total deferred credits and other liabilities	2,171,995		2,122,557
Total liabilities	6,043,177		5,819,851
Commitments and Contingencies (Note 11)
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:
PNMR common stockholders’ equity:
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 85,834,874 shares)	1,426,587		1,429,941
Accumulated other comprehensive income (loss), net of income taxes	(80,620)		(79,183)
Retained earnings	798,983		698,707
Total PNMR common stockholders’ equity	2,144,950		2,049,465
Non-controlling interest in Valencia	56,414		59,009
Total equity	2,201,364		2,108,474
	$	8,256,070	$	7,939,854

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

13

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(Unaudited)

	Attributable to PNMR								Non- controlling Interest in Valencia
	Common Stock		AOCI		Retained Earnings		Total PNMR Common Stockholders’ Equity				Total Equity
	(In thousands)
Balance at June 30, 2021	$	1,425,700	$	(79,353)	$	741,884	$	2,088,231	$	57,167	$	2,145,398
Net earnings before subsidiary preferred stock dividends	—		—		113,453		113,453		4,229		117,682
Total other comprehensive income (loss)	—		(1,267)		—		(1,267)		—		(1,267)
Subsidiary preferred stock dividends	—		—		(132)		(132)		—		(132)
Dividends declared on common stock	—		—		(56,222)		(56,222)		—		(56,222)
Awards of common stock	(129)		—		—		(129)		—		(129)
Stock based compensation expense	1,016		—		—		1,016		—		1,016
Valencia’s transactions with its owner	—		—		—		—		(4,982)		(4,982)
Balance at September 30, 2021	$	1,426,587	$	(80,620)	$	798,983	$	2,144,950	$	56,414	$	2,201,364
Balance at December 31, 2020	$	1,429,941	$	(79,183)	$	698,707	$	2,049,465	$	59,009	$	2,108,474
Net earnings before subsidiary preferred stock dividends	—		—		185,005		185,005		11,643		196,648
Total other comprehensive income (loss)	—		(1,437)		—		(1,437)		—		(1,437)
Subsidiary preferred stock dividends	—		—		(396)		(396)		—		(396)
Dividends declared on common stock	—		—		(84,333)		(84,333)		—		(84,333)
Awards of common stock	(10,082)		—		—		(10,082)		—		(10,082)
Stock based compensation expense	6,728		—		—		6,728		—		6,728
Valencia’s transactions with its owner	—		—		—		—		(14,238)		(14,238)
Balance at September 30, 2021	$	1,426,587	$	(80,620)	$	798,983	$	2,144,950	$	56,414	$	2,201,364

Balance at June 30, 2020	$	1,143,822	$	(92,581)	$	645,259	$	1,696,500	$	59,927	$	1,756,427
Net earnings before subsidiary preferred stock dividends	—		—		121,900		121,900		3,553		125,453
Total other comprehensive income	—		2,705		—		2,705		—		2,705
Subsidiary preferred stock dividends	—		—		(132)		(132)		—		(132)
Dividends declared on common stock	—		—		(48,987)		(48,987)		—		(48,987)
Stock based compensation expense	1,330		—		—		1,330		—		1,330
Valencia’s transactions with its owner	—		—		—		—		(4,201)		(4,201)
Balance at September 30, 2020	$	1,145,152	$	(89,876)	$	718,040	$	1,773,316	$	59,279	$	1,832,595
Balance at December 31, 2019	$	1,150,552	$	(99,377)	$	627,523	$	1,678,698	$	63,052	$	1,741,750
Net earnings before subsidiary preferred stock dividends	—		—		164,393		164,393		11,222		175,615
Total other comprehensive income	—		9,501		—		9,501		—		9,501
Subsidiary preferred stock dividends	—		—		(396)		(396)		—		(396)
Dividends declared on common stock	—		—		(73,480)		(73,480)		—		(73,480)
Proceeds from stock option exercise	24		—		—		24		—		24
Awards of common stock	(11,984)		—		—		(11,984)		—		(11,984)
Stock based compensation expense	6,560		—		—		6,560		—		6,560
Valencia’s transactions with its owner	—		—		—		—		(14,995)		(14,995)
Balance at September 30, 2020	$	1,145,152	$	(89,876)	$	718,040	$	1,773,316	$	59,279	$	1,832,595

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

14

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF EARNINGS

(Unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands)
Electric Operating Revenues:
Contracts with customers	$	361,701	$	341,850	$	884,559	$	825,759
Alternative revenue programs	(8,331)		(7,067)		(5,469)		(2,377)
Other electric operating revenue	82,153		29,721		151,595		50,043
Total electric operating revenues	435,523		364,504		1,030,685		873,425
Operating Expenses:
Cost of energy	170,902		108,284		383,556		250,692
Administrative and general	49,906		45,538		143,176		132,257
Energy production costs	32,374		31,148		106,709		98,111
Regulatory disallowances and restructuring costs	436		—		436		—
Depreciation and amortization	42,673		40,509		127,111		123,721
Transmission and distribution costs	12,844		12,075		34,906		34,265
Taxes other than income taxes	11,825		10,410		35,411		34,651
Total operating expenses	320,960		247,964		831,305		673,697
Operating income	114,563		116,540		199,380		199,728
Other Income and Deductions:
Interest income	3,364		3,239		10,376		9,882
Gains on investment securities	1,948		14,401		16,108		3,172
Other income	2,940		2,752		8,232		6,019
Other (deductions)	(3,530)		(5,590)		(10,635)		(10,700)
Net other income and deductions	4,722		14,802		24,081		8,373
Interest Charges	12,509		14,747		38,441		51,554
Earnings before Income Taxes	106,776		116,595		185,020		156,547
Income Taxes	15,500		13,591		26,178		16,127
Net Earnings	91,276		103,004		158,842		140,420
(Earnings) Attributable to Valencia Non-controlling Interest	(4,229)		(3,553)		(11,643)		(11,222)
Net Earnings Attributable to PNM	87,047		99,451		147,199		129,198
Preferred Stock Dividend Requirements	(132)		(132)		(396)		(396)
Net Earnings Available for PNM Common Stock	$	86,915	$	99,319	$	146,803	$	128,802

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

15

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands)
Net Earnings	$	91,276	$	103,004	$	158,842	$	140,420
Other Comprehensive Income:
Unrealized Gains on Available-for-Sale Debt Securities:
Net change in unrealized holding gains arising during the period, net of income tax (expense) benefit of $329, $(1,278), $246, and $(3,746)	(968)		3,755		(722)		11,004
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $632, $1,041, $2,062 and $1,818	(1,856)		(3,056)		(6,058)		(5,338)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience losses recognized as net periodic benefit cost, net of income tax (benefit) of $(530), $(527), $(1,590) and $(1,581)	1,557		1,548		4,671		4,644
Total Other Comprehensive Income (Loss)	(1,267)		2,247		(2,109)		10,310
Comprehensive Income	90,009		105,251		156,733		150,730
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(4,229)		(3,553)		(11,643)		(11,222)
Comprehensive Income Attributable to PNM	$	85,780	$	101,698	$	145,090	$	139,508

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

16

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine Months Ended September 30,
	2021		2020
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	158,842	$	140,420
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	151,775		147,790
Deferred income tax expense	24,034		16,607
(Gains) on investment securities	(16,108)		(3,172)
Regulatory disallowances and restructuring costs	436		—
Allowance for equity funds used during construction	(6,655)		(4,229)
Other, net	3,488		4,382
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(34,110)		(46,312)
Materials, supplies, and fuel stock	143		10,945
Other current assets	(20,398)		(5,661)
Other assets	14,541		19,184
Accounts payable	14,411		(2,481)
Accrued interest and taxes	13,370		564
Other current liabilities	12,442		9,022
Other liabilities	(34,394)		(30,820)
Net cash flows from operating activities	281,817		256,239
Cash Flows From Investing Activities:
Utility plant additions	(247,064)		(251,873)
Proceeds from sales of investment securities	396,870		489,218
Purchases of investment securities	(405,142)		(498,170)
Other, net	108		167
Net cash flows used in investing activities	(255,228)		(260,658)

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

17

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine Months Ended September 30,
	2021		2020
	(In thousands)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings (repayments), net	$	(10,000)	$	(36,300)
Long-term borrowings	235,000		852,845
Repayment of long-term debt	(200,000)		(752,845)
Dividends paid	(60,396)		(41,049)
Valencia’s transactions with its owner	(14,238)		(14,995)
Transmission interconnection and security deposit arrangements	28,278		2,212
Refunds paid under transmission interconnection arrangements	(2,450)		(4,400)
Debt issuance costs and other, net	(1,665)		1,077
Net cash flows from financing activities	(25,471)		6,545
Change in Cash, Restricted Cash, and Equivalents	1,118		2,126
Cash, Restricted Cash, and Equivalents at Beginning of Period	31,446		1,001
Cash, Restricted Cash, and Equivalents at End of Period	$	32,564	$	3,127
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	33,189	$	45,614
Income taxes paid (refunded), net	$	—	$	—
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	$	45,441	$	3,955

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

18

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2021		December 31, 2020
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	32,564	$	31,446
Accounts receivable, net of allowance for credit losses of $11,237 and $8,333	106,427		88,239
Unbilled revenues	49,782		43,724
Other receivables	27,836		21,814
Affiliate receivables	8,895		8,819
Materials, supplies, and fuel stock	60,330		60,472
Regulatory assets	28,387		—
Income taxes receivable	13,562		15,706
Other current assets	49,501		51,908
Total current assets	377,284		322,128
Other Property and Investments:
Investment securities	455,409		440,115
Other investments	12		120
Non-utility property, net	10,536		9,505
Total other property and investments	465,957		449,740
Utility Plant:
Plant in service, held for future use, and to be abandoned	6,134,271		6,022,753
Less accumulated depreciation and amortization	2,232,911		2,158,915
	3,901,360		3,863,838
Construction work in progress	201,612		148,962
Nuclear fuel, net of accumulated amortization of $48,062 and $41,367	97,055		100,801
Net utility plant	4,200,027		4,113,601
Deferred Charges and Other Assets:
Regulatory assets	452,596		457,953
Goodwill	51,632		51,632
Operating lease right-of-use assets, net of accumulated amortization	79,808		97,461
Other deferred charges	95,872		88,518
Total deferred charges and other assets	679,908		695,564
	$	5,723,176	$	5,581,033

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

19

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2021		December 31, 2020
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:
Short-term debt	$	—	$	10,000
Current installments of long-term debt	104,258		345,570
Accounts payable	90,020		121,050
Affiliate payables	5,336		14,058
Customer deposits	4,876		6,606
Accrued interest and taxes	43,856		32,630
Regulatory liabilities	13,381		5,419
Operating lease liabilities	26,166		25,130
Dividends declared	132		132
Transmission interconnection arrangement liabilities	30,983		6,883
Other current liabilities	38,114		26,854
Total current liabilities	357,122		594,332
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	1,628,184		1,351,050
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	619,003		579,150
Regulatory liabilities	661,272		664,873
Asset retirement obligations	191,384		182,718
Accrued pension liability and postretirement benefit cost	46,157		56,273
Operating lease liabilities	51,233		75,941
Other deferred credits	211,441		201,415
Total deferred credits and liabilities	1,780,490		1,760,370
Total liabilities	3,765,796		3,705,752
Commitments and Contingencies (Note 11)
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)	1,494,918		1,494,918
Accumulated other comprehensive income (loss), net of income taxes	(80,620)		(78,511)
Retained earnings	475,139		388,336
Total PNM common stockholder’s equity	1,889,437		1,804,743
Non-controlling interest in Valencia	56,414		59,009
Total equity	1,945,851		1,863,752
	$	5,723,176	$	5,581,033

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

20

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(Unaudited)

	Attributable to PNM
							Total PNM Common Stockholder’s Equity		Non- controlling  Interest in Valencia
	Common Stock		AOCI		Retained Earnings						Total Equity
	(In thousands)
Balance at June 30, 2021	$	1,494,918	$	(79,353)	$	448,224	$	1,863,789	$	57,167	$	1,920,956
Net earnings	—		—		87,047		87,047		4,229		91,276
Total other comprehensive income (loss)	—		(1,267)		—		(1,267)		—		(1,267)
Dividends declared on preferred stock	—		—		(132)		(132)		—		(132)
Dividends declared on common stock	—		—		(60,000)		(60,000)		—		(60,000)
Valencia’s transactions with its owner	—		—		—		—		(4,982)		(4,982)
Balance at September 30, 2021	$	1,494,918	$	(80,620)	$	475,139	$	1,889,437	$	56,414	$	1,945,851
Balance at December 31, 2020	$	1,494,918	$	(78,511)	$	388,336	$	1,804,743	$	59,009	$	1,863,752
Net earnings	—		—		147,199		147,199		11,643		158,842
Total other comprehensive income (loss)	—		(2,109)		—		(2,109)		—		(2,109)
Dividends declared on preferred stock	—		—		(396)		(396)		—		(396)
Dividends declared on common stock	—		—		(60,000)		(60,000)		—		(60,000)
Valencia’s transactions with its owner	—		—		—		—		(14,238)		(14,238)
Balance at September 30, 2021	$	1,494,918	$	(80,620)	$	475,139	$	1,889,437	$	56,414	$	1,945,851

Balance at June 30, 2020	$	1,264,918	$	(90,992)	$	272,345	$	1,446,271	$	59,927	$	1,506,198
Net earnings	—		—		99,451		99,451		3,553		103,004
Total other comprehensive income	—		2,247		—		2,247		—		2,247
Dividends declared on preferred stock	—		—		(132)		(132)		—		(132)
Valencia’s transactions with its owner	—		—		—		—		(4,201)		(4,201)
Balance at September 30, 2020	$	1,264,918	$	(88,745)	$	371,664	$	1,547,837	$	59,279	$	1,607,116
Balance at December 31, 2019	$	1,264,918	$	(99,055)	$	283,516	$	1,449,379	$	63,052	$	1,512,431
Net earnings	—		—		129,198		129,198		11,222		140,420
Total other comprehensive income	—		10,310		—		10,310		—		10,310
Dividends declared on preferred stock	—		—		(396)		(396)		—		(396)
Dividends declared on common stock	—		—		(40,654)		(40,654)		—		(40,654)
Valencia’s transactions with its owner	—		—		—		—		(14,995)		(14,995)
Balance at September 30, 2020	$	1,264,918	$	(88,745)	$	371,664	$	1,547,837	$	59,279	$	1,607,116

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

21

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF EARNINGS

(Unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands)
Electric Operating Revenues:
Contracts with customers	$	120,180	$	113,270	$	312,800	$	295,418
Alternative revenue programs	(1,152)		(5,309)		2,313		(5,107)
Total electric operating revenues	119,028		107,961		315,113		290,311
Operating Expenses:
Cost of energy	28,478		25,707		83,896		75,872
Administrative and general	11,708		11,868		34,960		33,398
Depreciation and amortization	23,031		22,492		67,696		66,696
Transmission and distribution costs	7,152		6,667		21,260		19,797
Taxes other than income taxes	9,817		9,448		26,730		25,249
Total operating expenses	80,186		76,182		234,542		221,012
Operating income	38,842		31,779		80,571		69,299
Other Income and Deductions:
Other income	2,144		3,546		4,853		6,245
Other (deductions)	(1,000)		(1,260)		(1,602)		(1,435)
Net other income and deductions	1,144		2,286		3,251		4,810
Interest Charges	8,403		7,942		25,155		22,475
Earnings before Income Taxes	31,583		26,123		58,667		51,634
Income Taxes	3,642		2,202		6,341		4,447
Net Earnings	$	27,941	$	23,921	$	52,326	$	47,187

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

22

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine Months Ended September 30,
	2021		2020
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	52,326	$	47,187
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	68,378		67,595
Deferred income tax (benefit)	(6,377)		(10,737)
Allowance for equity funds used during construction	(2,212)		(2,499)
Other, net	60		33
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(12,539)		(11,029)
Materials and supplies	(476)		(450)
Other current assets	(4,927)		(570)
Other assets	5,168		5,910
Accounts payable	(4,050)		952
Accrued interest and taxes	10,800		12,326
Other current liabilities	(754)		830
Other liabilities	11,538		4,258
Net cash flows from operating activities	116,935		113,806
Cash Flows From Investing Activities:
Utility plant additions	(233,381)		(228,976)
Net cash flows used in investing activities	(233,381)		(228,976)
Cash Flows From Financing Activities:
Short-term borrowings, net	—		494
Revolving credit facilities borrowings (repayments), net	—		(15,000)
Long-term borrowings	65,000		185,000
Equity contribution from parent	52,000		—
Transmission interconnection arrangements	3,600		6,402
Refunds paid under transmission interconnection arrangements	(7,302)		—
Dividends paid	—		(34,613)
Debt issuance costs and other, net	(736)		(2,113)
Net cash flows from financing activities	112,562		140,170
Change in Cash and Cash Equivalents	(3,884)		25,000
Cash and Cash Equivalents at Beginning of Period	14,800		1,000
Cash and Cash Equivalents at End of Period	$	10,916	$	26,000
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	25,085	$	22,340
Income taxes paid (refunded), net	$	892	$	969
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	$	14,166	$	1,443

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

23

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2021		December 31, 2020
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	10,916	$	14,800
Accounts receivable	34,399		25,171
Unbilled revenues	15,092		11,780
Other receivables	2,917		3,703
Materials and supplies	6,420		5,945
Regulatory assets	5,800		202
Other current assets	2,142		1,738
Total current assets	77,686		63,339
Other Property and Investments:
Other investments	136		164
Non-utility property, net	13,777		13,298
Total other property and investments	13,913		13,462
Utility Plant:
Plant in service and plant held for future use	2,320,978		2,193,270
Less accumulated depreciation and amortization	566,104		537,707
	1,754,874		1,655,563
Construction work in progress	134,895		61,359
Net utility plant	1,889,769		1,716,922
Deferred Charges and Other Assets:
Regulatory assets	91,836		99,837
Goodwill	226,665		226,665
Operating lease right-of-use assets, net of accumulated amortization	5,778		7,206
Other deferred charges	5,912		5,149
Total deferred charges and other assets	330,191		338,857
	$	2,311,559	$	2,132,580

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

24

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2021		December 31, 2020
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:
Accounts payable	$	15,404	$	33,620
Affiliate payables	3,982		5,883
Accrued interest and taxes	52,338		41,538
Regulatory liabilities	—		2,052
Operating lease liabilities	1,988		2,193
Other current liabilities	6,668		4,486
Total current liabilities	80,380		89,772
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	918,074		853,673
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	147,997		145,369
Regulatory liabilities	194,583		185,355
Asset retirement obligations	748		703
Accrued pension liability and postretirement benefit cost	700		1,828
Operating lease liabilities	3,579		4,779
Other deferred credits	35,494		25,423
Total deferred credits and other liabilities	383,101		363,457
Total liabilities	1,381,555		1,306,902
Commitments and Contingencies (Note 11)
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	737,166		685,166
Retained earnings	192,774		140,448
Total common stockholder’s equity	930,004		825,678
	$	2,311,559	$	2,132,580

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

25

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY-OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCKHOLDER’S EQUITY

(Unaudited)

	Common Stock		Paid-in Capital		Retained Earnings		Total Common Stockholder’s Equity
	(In thousands)
Balance at June 30, 2021	$	64	$	737,166	$	164,833	$	902,063
Net earnings	—		—		27,941		27,941
Balance at September 30, 2021	$	64	$	737,166	$	192,774	$	930,004
Balance at December 31, 2020	$	64	$	685,166	$	140,448	$	825,678
Net earnings	—		—		52,326		52,326
Equity contribution from parent	—		52,000		—		52,000
Balance at September 30, 2021	$	64	$	737,166	$	192,774	$	930,004

Balance at June 30, 2020	$	64	$	614,166	$	145,224	$	759,454
Net earnings	—		—		23,921		23,921
Dividends declared on common stock	—		—		(16,174)		(16,174)
Balance at September 30, 2020	$	64	$	614,166	$	152,971	$	767,201
Balance at December 31, 2019	$	64	$	614,166	$	140,397	$	754,627
Net earnings	—		—		47,187		47,187
Dividends declared on common stock	—		—		(34,613)		(34,613)
Balance at September 30, 2020	$	64	$	614,166	$	152,971	$	767,201

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

26

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    Significant Accounting Policies and Responsibility for Financial Statements

Financial Statement Preparation

In the opinion of management, the accompanying unaudited interim Condensed Consolidated Financial Statements reflect all normal and recurring accruals and adjustments that are necessary to present fairly the consolidated financial position at September 30, 2021 and December 31, 2020, and the consolidated results of operations and comprehensive income for the three and nine months ended September 30, 2021 and 2020 and cash flows for the nine months ended September 30, 2021 and 2020. 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. Weather causes the Company’s results of operations to be seasonal in nature and the results of operations presented in the accompanying Condensed Consolidated Financial Statements are not necessarily representative of operations for an entire year.

The Notes to Condensed Consolidated Financial Statements include disclosures for PNMR, PNM, and TNMP. This report uses the term “Company” when discussing matters of common applicability to PNMR, PNM, and TNMP. Discussions regarding only PNMR, PNM, or TNMP are so indicated. Certain amounts in the 2020 Condensed Consolidated Financial Statements and Notes thereto have been reclassified to conform to the 2021 financial statement presentation.

These Condensed Consolidated Financial Statements are unaudited. Certain information and note disclosures normally included in the annual audited Consolidated Financial Statements have been condensed or omitted, as permitted under the applicable rules and regulations. Readers of these financial statements should refer to PNMR’s, PNM’s, and TNMP’s audited Consolidated Financial Statements and Notes thereto that are included in their respective 2020 Annual Reports on Form 10-K.

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 Condensed Consolidated Financial Statements of each of PNMR, PNM, and TNMP include their accounts and those of subsidiaries in which that entity owns a majority voting interest. PNM also consolidates Valencia. See Note 6. PNM owns undivided interests in several 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 PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as equity transactions, and interconnection billings. See Note 15. All intercompany transactions and balances have been eliminated.

Dividends on Common Stock

Dividends on PNMR’s common stock are declared by the Board. The timing of the declaration of dividends is dependent on the timing of meetings and other actions of the Board. This has historically resulted in dividends attributable to the second quarter of each year being declared through actions of the Board during the third quarter of the year. The Board declared dividends on common stock considered to be for the second quarter of $0.3275 per share in July 2021 and $0.3075 per share in July 2020, which are reflected as being in the second quarter within "Dividends Declared per Common Share" on the PNMR Condensed Consolidated Statements of Earnings. The Board declared dividends on common stock for the third quarter of $0.3275 per share in September 2021 and $0.3075 per share in September 2020, which are reflected as being in the third quarter within "Dividends Declared per Common Share" on the PNMR Condensed Consolidated Statement of Earnings.

27

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

In the three and nine months ended September 30, 2021, PNMR made equity contributions of zero and $52.0 million to TNMP. PNM declared and paid cash dividends on its common stock to PNMR of $60.0 million in the three and nine months ended September 30, 2021 and zero and $40.7 million in the three and nine months ended September 30, 2020. TNMP did not declare or pay cash dividends on its common stock to PNMR in the three and nine months ended September 30, 2021. TNMP declared and paid cash dividends on its common stock to PNMR of $16.2 million and $34.6 million in the three and nine months ended September 30, 2020.

(2)     Segment Information

The following segment presentation is based on the methodology that management uses for making operating decisions and assessing performance of its various business activities. A reconciliation of the segment presentation to the GAAP financial statements is provided.

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, as well as providing transmission services to third parties. The sale of electricity includes the asset optimization of PNM’s jurisdictional capacity, as well as the capacity excluded from retail rates. FERC has jurisdiction over wholesale power and transmission rates.

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.

Corporate and Other

The Corporate and Other segment includes PNMR holding company activities, primarily related to corporate level debt and PNMR Services Company. The activities of PNMR Development, NM Capital, and the equity method investment in NMRD are also included in Corporate and Other. Eliminations of intercompany transactions are reflected in the Corporate and Other segment.

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

28

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

PNMR SEGMENT INFORMATION

	PNM		TNMP		Corporate and Other		PNMR Consolidated
	(In thousands)
Three Months Ended September 30, 2021
Electric operating revenues	$	435,523	$	119,028	$	—	$	554,551
Cost of energy	170,902		28,478		—		199,380
Utility margin	264,621		90,550		—		355,171
Other operating expenses	107,385		28,677		(4,058)		132,004
Depreciation and amortization	42,673		23,031		5,734		71,438
Operating income (loss)	114,563		38,842		(1,676)		151,729
Interest income (loss)	3,364		—		(35)		3,329
Other income	1,358		1,144		34		2,536
Interest charges	(12,509)		(8,403)		(2,332)		(23,244)
Segment earnings (loss) before income taxes	106,776		31,583		(4,009)		134,350
Income taxes (benefit)	15,500		3,642		(2,474)		16,668
Segment earnings (loss)	91,276		27,941		(1,535)		117,682
Valencia non-controlling interest	(4,229)		—		—		(4,229)
Subsidiary preferred stock dividends	(132)		—		—		(132)
Segment earnings (loss) attributable to PNMR	$	86,915	$	27,941	$	(1,535)	$	113,321
Nine Months Ended September 30, 2021
Electric operating revenues	$	1,030,685	$	315,113	$	—	$	1,345,798
Cost of energy	383,556		83,896		—		467,452
Utility margin	647,129		231,217		—		878,346
Other operating expenses	320,638		82,950		(6,379)		397,209
Depreciation and amortization	127,111		67,696		17,232		212,039
Operating income (loss)	199,380		80,571		(10,853)		269,098
Interest income	10,376		—		90		10,466
Other income (deductions)	13,705		3,251		(92)		16,864
Interest charges	(38,441)		(25,155)		(9,651)		(73,247)
Segment earnings (loss) before income taxes	185,020		58,667		(20,506)		223,181
Income taxes (benefit)	26,178		6,341		(5,986)		26,533
Segment earnings (loss)	158,842		52,326		(14,520)		196,648
Valencia non-controlling interest	(11,643)		—		—		(11,643)
Subsidiary preferred stock dividends	(396)		—		—		(396)
Segment earnings (loss) attributable to PNMR	$	146,803	$	52,326	$	(14,520)	$	184,609
At September 30, 2021:
Total Assets	$	5,723,176	$	2,311,559	$	221,335	$	8,256,070
Goodwill	$	51,632	$	226,665	$	—	$	278,297

29

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

	PNM		TNMP		Corporate and Other		PNMR Consolidated
	(In thousands)
Three Months Ended September 30, 2020
Electric operating revenues	$	364,504	$	107,961	$	—	$	472,465
Cost of energy	108,284		25,707		—		133,991
Utility margin	256,220		82,254		—		338,474
Other operating expenses	99,171		27,983		(4,885)		122,269
Depreciation and amortization	40,509		22,492		5,399		68,400
Operating income (loss)	116,540		31,779		(514)		147,805
Interest income	3,239		—		(59)		3,180
Other income	11,563		2,286		213		14,062
Interest charges	(14,747)		(7,942)		(4,574)		(27,263)
Segment earnings (loss) before income taxes	116,595		26,123		(4,934)		137,784
Income taxes (benefit)	13,591		2,202		(3,462)		12,331
Segment earnings (loss)	103,004		23,921		(1,472)		125,453
Valencia non-controlling interest	(3,553)		—		—		(3,553)
Subsidiary preferred stock dividends	(132)		—		—		(132)
Segment earnings (loss) attributable to PNMR	$	99,319	$	23,921	$	(1,472)	$	121,768
Nine Months Ended September 30, 2020
Electric operating revenues	$	873,425	$	290,311	$	—	$	1,163,736
Cost of energy	250,692		75,872		—		326,564
Utility margin	622,733		214,439		—		837,172
Other operating expenses	299,284		78,444		(14,644)		363,084
Depreciation and amortization	123,721		66,696		16,978		207,395
Operating income (loss)	199,728		69,299		(2,334)		266,693
Interest income	9,882		—		(208)		9,674
Other income (deductions)	(1,509)		4,810		(542)		2,759
Interest charges	(51,554)		(22,475)		(14,756)		(88,785)
Segment earnings (loss) before income taxes	156,547		51,634		(17,840)		190,341
Income taxes (benefit)	16,127		4,447		(5,848)		14,726
Segment earnings (loss)	140,420		47,187		(11,992)		175,615
Valencia non-controlling interest	(11,222)		—		—		(11,222)
Subsidiary preferred stock dividends	(396)		—		—		(396)
Segment earnings (loss) attributable to PNMR	$	128,802	$	47,187	$	(11,992)	$	163,997
At September 30, 2020:
Total Assets	$	5,449,238	$	2,075,291	$	217,583	$	7,742,112
Goodwill	$	51,632	$	226,665	$	—	$	278,297

The Company defines utility margin as electric operating revenues less cost of energy. Cost of energy consists primarily of fuel and purchase power costs for PNM and costs charged by third-party transmission providers for TNMP. The Company believes that utility margin provides a more meaningful basis for evaluating operations than electric operating revenues since substantially all such costs are offset in revenues as fuel and purchase power costs are passed through to customers under PNM’s FPPAC and third-party transmission costs are passed on to customers through TNMP’s transmission cost recovery factor. Utility margin is not a financial measure required to be presented and is considered a non-GAAP measure.

30

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(3)   Accumulated Other Comprehensive Income (Loss)

Information regarding accumulated other comprehensive income (loss) for the nine months ended September 30, 2021 and 2020 is as follows:

	Accumulated Other Comprehensive Income (Loss)
	PNM						Corporate and Other		PNMR Consolidated
	Unrealized Gains on Available-for-Sale Debt Securities		Pension Liability Adjustment				Fair Value Adjustment for Cash Flow Hedges
					Total				Total
	(In thousands)
Balance at December 31, 2020	$	20,403	$	(98,914)	$	(78,511)	$	(672)	$	(79,183)
Amounts reclassified from AOCI (pre-tax)	(8,120)		6,261		(1,859)		(903)		(2,762)
Income tax impact of amounts reclassified	2,062		(1,590)		472		229		701
Other OCI changes (pre-tax)	(968)		—		(968)		1,804		836
Income tax impact of other OCI changes	246		—		246		(458)		(212)
Net after-tax change	(6,780)		4,671		(2,109)		672		(1,437)
Balance at September 30, 2021	$	13,623	$	(94,243)	$	(80,620)	$	—	$	(80,620)

Balance at December 31, 2019	$	10,638	$	(109,693)	$	(99,055)	$	(322)	$	(99,377)
Amounts reclassified from AOCI (pre-tax)	(7,156)		6,225		(931)		(1,117)		(2,048)
Income tax impact of amounts reclassified	1,818		(1,581)		237		284		521
Other OCI changes (pre-tax)	14,750		—		14,750		33		14,783
Income tax impact of other OCI changes	(3,746)		—		(3,746)		(9)		(3,755)
Net after-tax change	5,666		4,644		10,310		(809)		9,501
Balance at September 30, 2020	$	16,304	$	(105,049)	$	(88,745)	$	(1,131)	$	(89,876)

The Condensed 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 Condensed Consolidated Statements of Earnings.

31

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(4)    Earnings Per Share

Dual presentation of basic and diluted earnings per share is presented in the Condensed Consolidated Statements of Earnings of PNMR. PNMR’s potentially dilutive shares consist of restricted stock and PNMR common stock issuable in 2020 under the PNMR 2020 Forward Equity Sale Agreements, which are calculated under the treasury stock method. See Note 7 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands, except per share amounts)
Net Earnings Attributable to PNMR	$	113,321	$	121,768	$	184,609	$	163,997
Average Number of Common Shares:
Outstanding during period	85,835		79,654		85,835		79,654
Vested awards of restricted stock	237		213		230		205
Average Shares – Basic	86,072		79,867		86,065		79,859
Dilutive Effect of Common Stock Equivalents:
PNMR 2020 Forward Equity Sale Agreements	—		—		—		57
Restricted stock	41		39		41		38
Average Shares – Diluted	86,113		79,906		86,106		79,954
Net Earnings Per Share of Common Stock:
Basic	$	1.32	$	1.52	$	2.14	$	2.05
Diluted	$	1.32	$	1.52	$	2.14	$	2.05

(5)   Electric Operating Revenues

PNMR is an investor-owned holding company with two regulated utilities providing electricity and electric services in New Mexico and Texas. PNMR’s electric utilities are PNM and TNMP.

Additional information concerning electric operating revenue is contained in Note 4 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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. As a result of the economic conditions resulting from the COVID-19 pandemic, PNM updated its allowance for accounts receivable balances and recorded incremental credit losses of $0.5 million and $2.9 million in the three and nine months ended September 30, 2021 and $2.0 million and $2.7 million in the three and nine months ended September 30, 2020. The NMPRC issued an order authorizing all public utilities to create a regulatory asset to defer incremental costs related to COVID-19, including increases in uncollectible accounts. See discussion regarding regulatory treatment in Note 12.

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 three and nine months ended September 30, 2021, PNM recorded $0.8 million in estimated credit losses related to these transactions.

In February 2021, Texas experienced a severe winter storm delivering the coldest temperatures in 100 years for many parts of the state. As a result, the ERCOT market was not able to deliver sufficient generation load to the grid resulting in significant, statewide outages as ERCOT directed transmission operators to curtail thousands of firm load megawatts. TNMP

32

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

complied with ERCOT directives to curtail delivery of electricity in its service territory and did not experience significant outages on its system outside of the ERCOT directed curtailments. During the weather event, generators experienced an extreme spike in market driven fuel prices and in turn charged REPs excessive market driven power prices which eventually get passed to end users on their electricity bill. Given the uncertainty of the collectability of end users' bills by REPs, ERCOT also increased the collateral required by REPs in order to do business within ERCOT's Balancing Authority. TNMP has deferred bad debt expense (credit losses) from defaulting REPs to a regulatory asset totaling $0.8 million at September 30, 2021 and will seek recovery in a general rate case.

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 alternative revenue program revenues ("ARP") and other revenues.

	PNM		TNMP		PNMR Consolidated
Three Months Ended September 30, 2021	(In thousands)
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	155,035	$	51,839	$	206,874
Commercial	137,071		34,434		171,505
Industrial	24,856		7,282		32,138
Public authority	7,388		1,614		9,002
Economy energy service	7,389		—		7,389
Transmission	26,459		24,075		50,534
Miscellaneous	3,503		936		4,439
Total revenues from contracts with customers	361,701		120,180		481,881
Alternative revenue programs	(8,331)		(1,152)		(9,483)
Other electric operating revenues	82,153		—		82,153
Total Electric Operating Revenues	$	435,523	$	119,028	$	554,551
Nine Months Ended September 30, 2021
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	377,794	$	121,600	$	499,394
Commercial	327,090		93,332		420,422
Industrial	66,593		21,621		88,214
Public authority	17,312		4,561		21,873
Economy energy service	24,722		—		24,722
Transmission	60,919		68,849		129,768
Miscellaneous	10,129		2,837		12,966
Total revenues from contracts with customers	884,559		312,800		1,197,359
Alternative revenue programs	(5,469)		2,313		(3,156)
Other electric operating revenues	151,595		—		151,595
Total Electric Operating Revenues	$	1,030,685	$	315,113	$	1,345,798

33

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

	PNM		TNMP		PNMR Consolidated
Three Months Ended September 30, 2020	(In thousands)
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	158,549	$	53,114	$	211,663
Commercial	125,414		31,077		156,491
Industrial	25,475		6,842		32,317
Public authority	7,982		1,468		9,450
Economy energy service	3,270		—		3,270
Transmission	17,463		19,845		37,308
Miscellaneous	3,697		924		4,621
Total revenues from contracts with customers	341,850		113,270		455,120
Alternative revenue programs	(7,067)		(5,309)		(12,376)
Other electric operating revenues	29,721		—		29,721
Total Electric Operating Revenues	$	364,504	$	107,961	$	472,465
Nine Months Ended September 30, 2020
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	370,448	$	122,315	$	492,763
Commercial	305,127		87,868		392,995
Industrial	65,313		20,232		85,545
Public authority	17,236		4,311		21,547
Economy energy service	11,802		—		11,802
Transmission	45,727		58,095		103,822
Miscellaneous	10,106		2,597		12,703
Total revenues from contracts with customers	825,759		295,418		1,121,177
Alternative revenue programs	(2,377)		(5,107)		(7,484)
Other electric operating revenues	50,043		—		50,043
Total Electric Operating Revenues	$	873,425	$	290,311	$	1,163,736

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 Condensed Consolidated Balance Sheets, net of allowance for credit losses, includes $98.6 million at September 30, 2021 and $86.2 million at December 31, 2020 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). The Company had no contract assets as of September 30, 2021 or December 31, 2020. 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. PNMR's, PNM's, and TNMP's contract liabilities and

34

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

related revenues are insignificant for all 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.

(6)     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. Additional information concerning PNM’s VIEs is contained in Note 10 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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 addition to variable operation and maintenance charges under this PPA. For the three and nine months ended September 30, 2021, PNM paid $5.0 million and $14.9 million for fixed charges and $0.7 million and $1.6 million for variable charges. For the three and nine months ended September 30, 2020, PNM paid $5.0 million and $15.0 million for fixed charges and $0.3 million and $1.2 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 Condensed Consolidated Financial Statements of PNM although PNM has no legal ownership interest or voting control of the VIE. The assets and liabilities of Valencia set forth below are immaterial to PNM and, therefore, not shown separately on the Condensed 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
	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands)
Operating revenues	$	5,719	$	5,278	$	16,425	$	16,126
Operating expenses	1,490		1,725		4,782		4,904
Earnings attributable to non-controlling interest	$	4,229	$	3,553	$	11,643	$	11,222

35

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

	Financial Position
	September 30,		December 31,
	2021		2020
	(In thousands)
Current assets	$	3,981	$	3,911
Net property, plant, and equipment	53,617		55,744
Total assets	57,598		59,655
Current liabilities	1,184		646
Owners’ equity – non-controlling interest	$	56,414	$	59,009

Westmoreland San Juan Mining, LLC

As discussed in the subheading Coal Supply in Note 11, PNM purchases coal for SJGS under the SJGS CSA. On October 9, 2018, Westmoreland filed a Current Report on Form 8-K with the SEC announcing it had filed voluntary petitions for relief under Chapter 11 of the U.S. Bankruptcy Code. On March 15, 2019, Westmoreland emerged from Chapter 11 bankruptcy as a privately held company owned and operated by a group of its former creditors. Under the reorganization, the assets of SJCC were sold to Westmoreland San Juan Mining, LLC (“WSJ LLC”), a subsidiary of Westmoreland Mining Holdings, LLC. As successor entity to SJCC, WSJ LLC assumed all rights and obligations of SJCC including obligations to PNM under the SJGS CSA and to PNMR under letter of credit support agreements.

PNMR issued $30.3 million in letters of credit to facilitate the issuance of reclamation bonds required in order for SJCC to mine coal to be supplied to SJGS. As discussed above, WSJ LLC assumed the rights and obligations of SJCC, including obligations to PNMR for the letters of credit. The letters of credit support results in PNMR having a variable interest in WSJ LLC since PNMR is subject to possible loss in the event performance by PNMR is required under the letters of credit support. PNMR 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 all reclamation costs are reimbursable under the SJGS CSA. Also, much of the mine reclamation activities will not be performed until after the expiration of the SJGS CSA. In addition, each of the SJGS participants has established and actively fund trusts to meet future reclamation obligations.

WSJ LLC is considered a VIE.  PNMR’s analysis of its arrangements with WSJ LLC concluded that WSJ LLC has the ability to direct its mining operations, which is the factor that most significantly impacts the economic performance of WSJ LLC.  Other than PNM being able to ensure that coal is supplied in adequate quantities and of sufficient quality to provide the fuel necessary to operate SJGS in a normal manner, the mining operations are solely under the control of WSJ LLC, including developing mining plans, hiring of personnel, and incurring operating and maintenance expenses. Neither PNMR nor PNM has any ability to direct or influence the mining operation.  PNM’s involvement through the SJGS CSA is a protective right rather than a participating right and WSJ LLC has the power to direct the activities that most significantly impact the economic performance of WSJ LLC.  The SJGS CSA requires WSJ LLC to deliver coal required to fuel SJGS in exchange for payment of a set price per ton, which is escalated over time for inflation.  If WSJ LLC is able to mine more efficiently than anticipated, its economic performance will be improved.  Conversely, if WSJ LLC cannot mine as efficiently as anticipated, its economic performance will be negatively impacted.  Accordingly, PNMR believes WSJ LLC is the primary beneficiary and, therefore, WSJ LLC is not consolidated by either PNMR or PNM. The amounts outstanding under the letters of credit support constitute PNMR’s maximum exposure to loss from the VIE at September 30, 2021.

(7)    Fair Value of Derivative and Other Financial Instruments

Additional information concerning energy related derivative contracts and other financial instruments is contained in Note 9 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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

36

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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.

In the third quarter of 2021, PNM entered into three agreements to purchase power from third parties at a fixed price in order to ensure that customer demand during the 2022 summer peak load period is met. Two of the agreements, the purchase of 85 MW from June through September 2022 and the purchase of 40 MW for the full year of 2022, are not considered derivatives because there are no notional amounts due to the unit-contingent nature of the agreements. The third agreement for the purchase of 150 MW firm power in June and September 2022 meets the definition of an economic hedge described below and has been accounted for accordingly.

Beginning January 1, 2018, PNM is exposed to market risk for its 65 MW interest in SJGS Unit 4, which is held as merchant plant as ordered by the NMPRC. PNM has entered into agreements to sell power from 36 MW of that capacity to a third party at a fixed price for the period January 1, 2018 through May 31, 2022, subject to certain conditions. Under these agreements, PNM is obligated to deliver 36 MW of power only when SJGS Unit 4 is operating.  These agreements are not considered derivatives because there is no notional amount due to the unit-contingent nature of the transactions.

PNM and Tri-State have a hazard sharing agreement that expires in May 2022. Under this agreement, each party sells the other party 100 MW of capacity and energy from a designated generation resource on a unit contingent basis, subject to certain performance guarantees.  Both the purchases and sales are made at the same market index price.  This agreement serves to reduce the magnitude of each party’s single largest generating hazard and assists in enhancing the reliability and efficiency of their respective operations. PNM passes the sales and purchases through to customers under PNM’s FPPAC.

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.

Unusually cold weather in February 2021 resulted in higher than expected natural gas and purchased power costs. PNM mitigated the impacts from the cold weather by securing gas supplies in advance, engaging in market purchases when lower prices were available, and adjusting plant operation of its gas units to minimize reliance on higher-priced gas supplies. PNM estimates the impact of the cold weather conditions in the first quarter of 2021 resulted in approximately $20 million of additional natural gas costs and approximately $8 million in additional purchased power costs. These fuel increases are being passed through to customers under the FPPAC over the remainder of 2021.

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 nine months ended September 30, 2021 and the year ended December 31, 2020, PNM was not hedging its exposure to the variability in future cash flows from commodity derivatives through designated cash flows 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

37

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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 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 Condensed Consolidated Balance Sheets:

	Economic Hedges
	September 30, 2021		December 31, 2020
	(In thousands)
Other current assets	$	753	$	1,096
Other deferred charges	—		455
	753		1,551
Other current liabilities	(2,703)		(1,096)
Other deferred credits	—		(455)
	(2,703)		(1,551)
Net	$	(1,950)	$	—

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. Included in the table above are equal amounts of current assets and current liabilities aggregating $0.7 million at September 30, 2021. All of the assets and liabilities in the table above at December 31, 2020 result from PNM’s hazard sharing arrangements with Tri-State. The hazard sharing arrangements are net-settled upon delivery.

As discussed above, PNM has a NMPRC-approved hedging plan to manage fuel and purchased power costs related to customers covered by its FPPAC. The table above includes less than $0.1 million in current assets and $2.0 million of current liabilities related to this plan at September 30, 2021. There were no amounts hedged under this plan as of December 31, 2020.

At September 30, 2021 and December 31, 2020, PNM had no amounts recognized for the legal right to reclaim cash collateral. However, at both September 30, 2021 and December 31, 2020, amounts posted as cash collateral under margin arrangements were $0.5 million, which is included in other current assets on the Condensed Consolidated Balance Sheets. At both September 30, 2021 and December 31, 2020, obligations to return cash collateral were $0.9 million, which is included in other current liabilities and other deferred credits on the Condensed Consolidated Balance Sheets.

The effects of mark-to-market commodity derivative instruments on PNM’s revenues and cost of energy during the three and nine months ended September 30, 2021 and 2020 were less than $0.1 million. Commodity derivatives had no impact on OCI for any of the periods presented.

PNM's net buy (sell) volume positions for energy were 111,512 MWh and zero MWh at September 30, 2021 and December 31, 2020. PNM had no open gas commodity volume positions at September 30, 2021 or December 31, 2020.

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. At September 30, 2021 and December 31, 2020, PNM had no such contracts in a net liability position.

38

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Non-Derivative Financial Instruments

The carrying amounts reflected on the Condensed 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 and trusts for PNM’s share of final reclamation costs related to the coal mines serving SJGS and Four Corners. See Note 11. At September 30, 2021 and December 31, 2020, the fair value of investment securities included $392.2 million and $379.2 million for the NDT and $63.2 million and $60.9 million for the 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. At September 30, 2021 and December 31, 2020, PNM had 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 Condensed Consolidated Statements of Earnings related to investment securities in the NDT and reclamation trusts are presented in the following table:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands)
Equity securities:
Net gains (losses) from equity securities sold	$	(309)	$	90	$	5,931	$	4,131
Net gains (losses) from equity securities still held	(3,153)		8,545		2,388		2,991
Total net gains (losses) on equity securities	(3,462)		8,635		8,319		7,122
Available-for-sale debt securities:
Net gains (losses) on debt securities	5,410		5,766		7,789		(3,950)
Net gains on investment securities	$	1,948	$	14,401	$	16,108	$	3,172

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 $0.6 million and $1.2 million for the three and nine months ended September 30, 2021 and $4.2 million and $(4.5) million for the three and nine months ended September 30, 2020.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands)
Proceeds from sales	$	128,683	$	134,567	$	396,870	$	489,218
Gross realized gains	$	10,986	$	12,998	$	30,290	$	30,085
Gross realized (losses)	$	(6,527)	$	(11,374)	$	(17,776)	$	(25,411)

At September 30, 2021, the available-for-sale debt securities held by PNM, had the following final maturities:

	Fair Value
	(In thousands)
Within 1 year	$	26,085
After 1 year through 5 years	77,703
After 5 years through 10 years	93,532
After 10 years through 15 years	21,475
After 15 years through 20 years	13,858
After 20 years	33,306
	$	265,959

39

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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. Level 3 inputs are unobservable inputs for the asset or liability.

For investment securities, Level 2 and Level 3 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. 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. The valuation of Level 3 investments, when applicable, 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 Company has no Level 3 investments as of September 30, 2021 and December 31, 2020. Management of the Company independently verifies the information provided by pricing services.

Items recorded at fair value by PNM on the Condensed 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)
September 30, 2021
Cash and cash equivalents	$	8,229	$	8,229	$	—
Equity securities:
Corporate stocks, common	99,681		99,681		—
Corporate stocks, preferred	9,046		3,256		5,790
Mutual funds and other	72,494		72,404		90
Available-for-sale debt securities:
U.S. government	44,408		14,914		29,494		$	270
International government	16,925		—		16,925		1,782
Municipals	47,860		—		47,860		1,896
Corporate and other	156,766		—		156,766		14,351
	$	455,409	$	198,484	$	256,925	$	18,299

40

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Unrealized Gains
	(In thousands)
December 31, 2020
Cash and cash equivalents	$	6,107	$	6,107	$	—
Equity securities:
Corporate stocks, common	85,271		85,271		—
Corporate stocks, preferred	9,910		3,608		6,302
Mutual funds and other	58,817		58,762		55
Available-for-sale debt securities:
U.S. government	55,839		29,579		26,260		$	950
International government	16,032		—		16,032		2,537
Municipals	50,139		—		50,139		2,779
Corporate and other	158,000		3		157,997		21,121
	$	440,115	$	183,330	$	256,785	$	27,387

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 Condensed Consolidated Balance Sheets, are presented below:

	Carrying Amount		Fair Value
September 30, 2021	(In thousands)
PNMR	$	3,500,233	$	3,724,723
PNM	$	1,732,442	$	1,834,677
TNMP	$	918,074	$	1,040,046
December 31, 2020
PNMR	$	3,295,150	$	3,355,761
PNM	$	1,696,620	$	1,602,547
TNMP	$	853,673	$	1,006,722

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

(8)    Stock-Based Compensation

PNMR has various stock-based compensation programs, including stock options, restricted stock, and performance shares granted under the Performance Equity Plan (“PEP”). Although certain PNM and TNMP employees participate in the PNMR plans, PNM and TNMP do not have separate employee stock-based compensation plans. The Company has not awarded stock options since 2010 and all employee stock options expired or were exercised as of February 2020. Certain restricted stock awards are subject to achieving performance or market targets. Other awards of restricted stock are only subject to time vesting requirements. Additional information concerning stock-based compensation under the PEP is contained in Note 12 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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 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.

41

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Compensation expense for other such awards is amortized 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. At September 30, 2021, PNMR had unrecognized expense related to stock awards of $5.2 million, which is expected to be recognized over an average of 1.7 years.

PNMR receives a tax deduction for certain stock option exercises during the period the options are exercised, generally for the excess of the price at which the options are sold over the exercise prices of the options, and a tax deduction for the value of restricted stock at the vesting date. All excess tax benefits and deficiencies are recorded to tax expense and classified as operating cash flows when used to reduce income taxes payable. See Note 14.

The grant date fair value for restricted stock and stock awards with internal Company performance targets is determined based on the market price of PNMR 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.

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

	Nine Months Ended September 30,
Restricted Shares and Performance Based Shares	2021			2020
Expected quarterly dividends per share	$	0.3275		$	0.3075
Risk-free interest rate	0.32		%	0.72		%
Market-Based Shares
Dividend yield	2.76		%	2.51		%
Expected volatility	33.69		%	19.41		%
Risk-free interest rate	0.29		%	0.72		%

The following table summarizes activity in restricted stock awards, including performance-based and market-based shares for the nine months ended September 30, 2021:

	Restricted Stock
	Shares	Weighted- Average Grant Date Fair Value
Outstanding at December 31, 2020	168,061	$	40.77
Granted	213,515	43.48
Exercised	(210,572)	40.73
Forfeited	(1,741)	43.72
Outstanding at September 30, 2021	169,263	$	43.71

PNMR’s current stock-based compensation program provides for performance and market targets through 2023. Included in the above table are 124,941 previously awarded shares that were earned for the 2018-2020 performance measurement period and ratified by the Board in February 2021 (based upon achieving market and performance targets at near "maximum" levels). Excluded from the table above are 142,080, 142,047 and 152,414 shares for the three-year performance periods ending in 2021, 2022 and 2023 that will be awarded if all performance and market criteria are achieved at maximum levels and all executives remain eligible.

42

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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

	Nine Months Ended September 30,
Restricted Stock	2021		2020
Weighted-average grant date fair value	$	43.48	$	36.73
Total fair value of restricted shares that vested (in thousands)	$	10,018	$	11,740
Stock Options
Total intrinsic value of options exercised (in thousands)	$	—	$	84

(9)   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 contains a single financial covenant that requires the maintenance of a debt-to-capitalization ratio. For the PNMR 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. Additional information concerning financing activities is contained in Note 7 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

Financing Activities

At December 31, 2020, PNM had $146.0 million of outstanding PCRBs, which have a final maturity of April 1, 2033. These PCRBs were subject to mandatory tender on October 1, 2021 and were successfully remarketed to new investors on that date. The $146.0 million PCRBs bear interest at a fixed rate of 2.15% until their final maturity.

On September 23, 2021, PNM entered into an agreement (the "PNM September 2021 Note Purchase Agreement") with institutional investors for the sale and issuance of $150.0 million aggregate principal amount of two series of Senior Unsecured Notes (the "PNM September 2021 SUNs") to be offered in private placement transactions. The PNM September 2021 SUNs will be issued on or before December 30, 2021. PNM will issue $50.0 million of the PNM September 2021 SUNs at 2.29%, due December 30, 2031, and another $100.0 million at 2.97%, due December 30, 2041. Proceeds from the PNM September 2021 SUNs will be used for funding of capital expenditures, including the purchase of the Western Spirit transmission line, repayment of existing indebtedness, and for general corporate purposes. The PNM September 2021 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 September 2021 SUNs at par. Although there are customary change of control provisions in the PNM debt agreements, the change of control provisions in these agreements, including the PNM September 2021 Note Purchase Agreement, are not triggered by the closing of the Merger. PNM has the right to redeem any or all of the PNM September 2021 SUNs prior to their maturities, subject to payment of a customary make-whole premium.

On July 14, 2021, TNMP entered into an agreement (the "TNMP 2021 Bond Purchase Agreement") with institutional investors for the sale of $65.0 million aggregate principal amount of one series of TNMP first mortgage bonds (the "TNMP 2021 Bonds") offered in private placement transactions. On August 16, 2021, TNMP issued all $65.0 million of the TNMP 2021 Bonds at 2.44% with a maturity of August 15, 2035 and used the proceeds to repay existing debt and for other corporate purposes. The TNMP 2021 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the supplemental indenture governing the TNMP 2021 Bonds. The terms of the supplemental indenture governing the TNMP 2021 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 2021 Bonds at par. However, the definition of change of control in the supplemental indenture governing the TNMP 2021 Bonds will not be triggered by the closing of the Merger. TNMP has the right to redeem any or all of the TNMP 2021 Bonds prior to their maturity, subject to payment of a customary make-whole premium.

43

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

On July 14, 2021, PNM entered into an agreement (the "PNM 2021 Note Purchase Agreement") with institutional investors for the sale and issuance of $160.0 million aggregate principal amount of two series of Senior Unsecured Notes (the "PNM 2021 SUNs") offered in private placement transactions. The PNM 2021 SUNs were issued on July 14, 2021. PNM issued $80.0 million of the PNM 2021 SUNs at 2.59%, due July 15, 2033, and another $80.0 million at 3.14%, due July 15, 2041. Proceeds from the PNM 2021 SUNs were used to repay the total amount of $160.0 million of PNM's 5.35% SUNs, at par, earlier than their scheduled maturity of October 1, 2021. The PNM 2021 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 2021 SUNs at par. Although there are customary change of control provisions in the PNM debt agreements, the change of control provisions in these agreements, including the PNM 2021 Note Purchase Agreement, are not triggered by the closing of the Merger. PNM has the right to redeem any or all of the PNM 2021 SUNs prior to their maturities, subject to payment of a customary make-whole premium.

On June 18, 2021, PNM entered into a $75.0 million term loan (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 and for other corporate purposes. The PNM 2021 Term Loan bears interest at a variable rate, which was 0.91% at September 30, 2021 and matures on December 18, 2022.

On May 18, 2021, PNMR entered into a $1.0 billion delayed-draw term loan agreement (the “PNMR 2021 Delayed-Draw Term Loan”), among PNMR, the lenders party thereto, and Wells Fargo Bank, National Association, as administrative agent. Initially PNMR drew $850.0 million to repay and terminate existing indebtedness including the $150.0 million PNMR 2019 Term Loan, the $300.0 million PNMR 2020 Delayed-Draw Term Loan, the $150.0 million PNMR 2020 Term Loan, $92.1 million in borrowings under the PNMR Revolving Credit Facility, the $65.0 million PNMR Development Term Loan, and $40.0 million in borrowings under the PNMR Development Revolving Credit Facility, which was then terminated. Draws on the PNMR 2021 Delayed-Draw Term Loan bear interest at a variable rate, which was 0.94% at September 30, 2021, and mature on May 18, 2023.

The PNMR 2021 Delayed-Draw Term Loan provides that substantially concurrently with the consummation of the transactions set forth in the Merger Agreement, PNMR will assign to Avangrid all of its rights, duties, obligations and liabilities under the PNMR 2021 Delayed-Draw Term Loan and Avangrid will assume from PNMR, as its direct and primary obligation, the payment and performance of all of the duties, liabilities and obligations of PNMR under the PNMR 2021 Delayed-Draw Term Loan pursuant to an amendment and restatement of the PNMR 2021 Delayed-Draw Term Loan in the form of an amended and restated credit agreement attached to the PNMR 2021 Delayed-Draw Term Loan.

On April 24, 2020, TNMP entered into an agreement (the "TNMP 2020 Bond Purchase Agreement") with institutional investors for the sale of $185.0 million aggregate principal amount of four series of TNMP first mortgage bonds (the "TNMP 2020 Bonds") offered in private placement transactions. TNMP issued $110.0 million of TNMP 2020 Bonds on April 24, 2020 and used the proceeds to repay borrowings under the TNMP Revolving Credit Facility and for other corporate purposes. TNMP issued the remaining $75.0 million of TNMP 2020 Bonds on July 15, 2020 and used the proceeds from that issuance to repay borrowings under the TNMP Revolving Credit facility and for other corporate purposes. The TNMP 2020 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the indenture governing the TNMP 2020 Bonds. The terms of the supplemental indenture governing the TNMP 2020 Bonds include the customary covenants discussed above. In the event of a change of control, including the closing of the Merger, TNMP will be required to offer to prepay the TNMP 2020 Bonds at par. TNMP has the right to redeem any or all of the TNMP 2020 Bonds prior to their respective maturities, subject to payment of a customary make-whole premium.

On April 15, 2020, PNM entered into a $250.0 million term loan agreement (the "PNM 2020 Term Loan"), between PNM, the lenders party thereto, and U.S. Bank, as administrative agent. Proceeds from the PNM 2020 Term Loan were used to prepay the PNM 2019 $250.0 million Term Loan due July 2020, without penalty. As discussed below, on April 30, 2020, PNM used $100.0 million of proceeds from the PNM 2020 SUNs to prepay without penalty an equal amount of the PNM 2020 Term Loan. On December 21, 2020, PNM prepaid without penalty the remaining $150.0 million balance of the PNM 2020 Term Loan.

On April 30, 2020, PNM entered into an agreement (the "PNM 2020 Note Purchase Agreement") with institutional investors for the sale of $200.0 million aggregate principal amount of senior unsecured notes offered in private placement transactions. Under the agreement, on April 30, 2020, PNM issued $150.0 million aggregate principal amount of its 3.21% senior unsecured notes, Series A, due April 30, 2030, and $50.0 million of its aggregate principal amount of its 3.57% senior unsecured notes, Series B, due April 29, 2039 (the "PNM 2020 SUNs"). PNM used $100.0 million of proceeds from the PNM 2020 SUNs to repay an equal amount of the PNM 2020 Term Loan. The remaining $100.0 million of the PNM 2020 SUNs

44

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

were used to repay borrowings on the PNM Revolving Credit Facility and for other corporate purposes. The PNM 2020 Note Purchase Agreement includes the customary covenants discussed above. Although there are customary change of control provisions in the PNM debt agreements, including the PNM 2020 Note Purchase Agreement, the change of control provisions in these agreements are not triggered by the closing of the Merger. PNM has the right to redeem any or all of the PNM 2020 SUNs prior to their maturities, subject to payment of a customary make-whole premium.

At December 31, 2019, PNM had $40.0 million of outstanding PCRBs, which have a final maturity of June 1, 2040 and two series of outstanding PCRBs of $39.3 million and $21.0 million, which have a final maturity of June 1, 2043. These PCRBs, aggregating $100.3 million, were subject to mandatory tender on June 1, 2020. On June 1, 2020, PNM purchased these PCRBs utilizing borrowings under the PNM Revolving Credit Facility and converted the PCRBs to the weekly mode. PNM held these PCRBs (without legally canceling them) until July 1, 2020, when they were remarketed in the weekly mode (the "PNM Floating Rate PCRBs") and PNM used the remarketing proceeds to repay the revolver borrowings. PNM Floating Rate PCRBs in the weekly mode bore interest at rates that were reset weekly, giving investors the option to return the PCRBs for remarketing to new investors upon 7 days' notice. At September 30, 2021, this rate was 0.11%. A corresponding portion of the borrowing capacity under the PNM Revolving Credit Facility was reserved to support the investors' option to return the PNM Floating Rate PCRBs upon 7 days' notice. On October 1, 2021 PNM converted the PNM Floating Rate PCRBs to a fixed rate period and successfully remarketed them to new investors ("PNM 2021 Fixed Rate PCRBs"). The PNM 2021 Fixed Rate PCRBs now bear interest at 0.875% and are subject to mandatory tender on October 1, 2026.

At June 30, 2020 and December 31, 2019, PNM had PCRBs outstanding of $36.0 million at 6.25% issued by the Maricopa County, Arizona Pollution Control Corporation as well as $255.0 million at 5.90% and $11.5 million at 6.25% issued by the City of Farmington, New Mexico. The $36.0 million PCRBs became callable at 101% of par on January 1, 2020 and the remaining $266.5 million PCRBs became callable at par on June 1, 2020. On June 22, 2020, PNM provided notice to the bondholders that it was calling the PCRBs aggregating $302.5 million. On July 22, 2020, PNM purchased the PCRBs in lieu of redemption and remarketed them to new investors (the "PNM 2020 Fixed Rate PCRBs"). Information concerning the funding dates, mandatory tender dates, and interest rates on the PNM 2020 Fixed Rate PCRBs can be found in Note 7 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

In August 2020, PNMR entered into letter of credit arrangements with Wells Fargo Bank, N.A. (the "WFB LOC Facility") under which letters of credit aggregating $30.3 million were issued to facilitate the posting of reclamation bonds currently held by WSJ LLC (who assumed all the obligations of SJCC post-bankruptcy). The reclamation bonds were required to be posted in connection with permits relating to the operation of the San Juan mine.

On March 9, 2018, PNMR issued $300.0 million aggregate principal amount of 3.25% SUNs (the “PNMR 2018 SUNs”), which were set to mature on March 9, 2021. On December 22, 2020, PNMR entered into the $300.0 million PNMR 2020 Delayed-Draw Term Loan that would have matured in January 2022 and drew $80.0 million to refinance existing indebtedness and for other corporate purposes. On March 9, 2021, PNMR utilized the remaining $220.0 million of capacity under the PNMR 2020 Delayed-Draw Term Loan to repay an equivalent amount of the PNMR 2018 SUNs. The remaining $80.0 million repayment of the PNMR 2018 SUNs was funded through borrowings under the PNMR Revolving Credit Facility.

On October 20, 2020, the execution of the Merger Agreement constituted a “Change of Control” under certain PNMR, TNMP, and PNMR Development debt agreements. Under each of the specified debt agreements, a “Change of Control” constitutes an “Event of Default,” pursuant to which the lender parties thereto have the right to accelerate the indebtedness under the debt agreements. The definition of Change of Control under the PNM debt agreements and PNM note purchase agreements was not triggered by the execution of the Merger Agreement.

On October 26, 2020, PNMR, TNMP and PNMR Development entered into amendment agreements with the lender parties thereto to amend the definition of "Change of Control" such that the entry into the Merger Agreement would not constitute a Change of Control and to waive the Event of Default arising from entry into the Merger Agreement. On September 15, 2021, PNMR and TNMP entered into amendment agreements with the lender parties thereto to further amend the definition of "Change of Control" such that the closing of the Merger does not constitute a Change of Control. The Change of Control provisions in the PNM debt agreements, PNM note purchase agreements, and TNMP 2021 Bond Purchase Agreement are not triggered by the closing of the Merger and did not require amendment.

The documents governing TNMP's aggregate $750.0 million of outstanding 2014 to 2020 First Mortgage Bonds ("TNMP FMBs") obligated TNMP to offer, within 30 business days following the signing of the Merger Agreement, to prepay all $750.0 million outstanding TNMP FMBs at 100% of the principal amount, plus accrued and unpaid interest thereon, but without any make-whole amount or other premium. TNMP made such offer to prepay the TNMP FMBs in accordance with the

45

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

terms of the TNMP FMBs, and none of the holders of the TNMP FMBs accepted TNMP’s offer. The documents governing the 2014 to 2020 TNMP FMBs require TNMP to make another offer, within 30 business days of closing of the Merger, to prepay all $750.0 million outstanding TNMP FMBs at par. TNMP will make such offer to prepay all $750.0 million outstanding TNMP FMBs in accordance with the terms of the TNMP FMBs; however, holders of the TNMP FMBs are not required to tender their TNMP FMBs and may accept or reject such offer to prepay. As discussed above, the supplemental indenture that governs the TNMP 2021 Bonds excludes the Merger from the definition of Change of Control.

The TNMP FMBs are not registered under the Securities Act and may not be offered or sold in the United States absent registration or applicable exemption from registration requirements and applicable state laws. The information in this Quarterly Report on Form 10-Q is for informational purposes only and is neither an offer to purchase, nor a solicitation of an offer to sell, subscribe for or buy any securities in any jurisdiction pursuant to the proposed transactions or otherwise, nor shall there be any sale, issuance or transfer of securities in any jurisdiction in contravention of applicable law. Similar to the offer to prepay made after signing the Merger Agreement, the post-Merger closing offer to prepay the TNMP FMBs will be made only pursuant to an offer to prepay, which will set forth the terms and conditions of the offer to prepay.

At September 30, 2021, variable interest rates were 0.94% on the PNMR 2021 Delayed-Draw Term Loan that matures in May 2023, 0.91% on the PNM 2021 Term Loan that matures in December 2022, and 0.11% on the PNM Floating Rate PCRBs in the weekly mode.

Short-term Debt and Liquidity

Currently, the PNMR Revolving Credit Facility has a financing capacity of $300.0 million and the PNM Revolving Credit Facility has a financing capacity of $400.0 million. Both facilities currently expire on October 31, 2023 and contain options to be extended through October 2024, subject to approval by a majority of the lenders. PNM also has the $40.0 million PNM 2017 New Mexico Credit Facility that expires on December 12, 2022. The TNMP Revolving Credit Facility is a $75.0 million revolving credit facility secured by $75.0 million aggregate principal amount of TNMP first mortgage bonds that matures on September 23, 2022 and contains two one-year extension options, subject to approval by a majority of the lenders. PNMR Development had a $40.0 million revolving credit facility that was set to expire on January 31, 2022. As discussed above, on May 18, 2021, the PNMR Development Revolving Credit Facility was terminated. Variable interest rates under these facilities are based on LIBOR but contain provisions which allow for the replacement of LIBOR with other widely accepted interest rates.

Short-term debt outstanding consists of:

	September 30,		December 31,
Short-term Debt	2021		2020
	(In thousands)
PNM:
PNM 2017 New Mexico Credit Facility	$	—	$	10,000
PNMR:
PNMR Revolving Credit Facility	13,900		12,000
PNMR Development Revolving Credit Facility	—		10,000
	$	13,900	$	32,000

At September 30, 2021, the weighted average interest rate was 1.58% for the PNMR Revolving Credit Facility. There were no borrowings outstanding under the PNM Revolving Credit Facility, the PNM 2017 New Mexico Revolving Credit Facility, or the TNMP Revolving Credit Facility at September 30, 2021.

In addition to the above borrowings, PNMR, PNM, and TNMP had letters of credit outstanding of $3.4 million, $2.2 million, and zero at September 30, 2021 that reduce the available capacity under their respective revolving credit facilities. The above table excludes intercompany debt. As of September 30, 2021 and December 31, 2020, neither PNM nor TNMP had any intercompany borrowings from PNMR. PNMR Development had $0.1 million and $0.3 million in intercompany borrowings from PNMR at September 30, 2021 and December 31, 2020. PNMR had no intercompany borrowings from PNM, TNMP, or PNMR Development at either of September 30, 2021 or December 31, 2020.

46

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

In 2017, PNMR entered into three separate four-year hedging agreements whereby it effectively established fixed interest rates of 1.926%, 1.823%, and 1.629%, plus customary spreads over LIBOR for three separate tranches, each of $50.0 million, of its variable rate debt. On March 23, 2021 the 1.926% fixed interest rate hedge agreement expired according to its terms and the remaining agreements expired on May 23, 2021.

At October 22, 2021, PNMR, PNM, and TNMP had availability of $286.0 million, $397.8 million, and $75.0 million under their respective revolving credit facilities, including reductions of availability due to outstanding letters of credit. PNM also had $40.0 million of availability under the PNM 2017 New Mexico Credit Facility. Total availability at October 22, 2021, on a consolidated basis, was $798.8 million for PNMR. As of October 22, 2021, PNM and TNMP had no borrowings from PNMR under their intercompany loan agreements however, PNMR Development had $0.2 million in borrowings from PNMR. PNMR had no borrowings from PNM, TNMP, or PNMR Development. At October 22, 2021, PNMR, PNM, and TNMP had invested cash of $0.9 million, $61.8 million, and $11.4 million.

The Company’s debt arrangements have various maturities and expiration dates. PNM has $104.5 million of PCRBs that must be repriced in June 2022. Additional information on debt maturities is contained in Note 7 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

(10)   Pension and Other Postretirement Benefit Plans

PNMR 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”). PNMR 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. The Company presents the service cost component of its net periodic benefit costs in administrative and general expenses and the non-service costs components in other income (deductions), net of amounts capitalized or deferred to regulatory assets and liabilities, on the Condensed Consolidated Statements of Earnings. PNM and TNMP receive a regulated return on the amounts funded for pension and OPEB plans in excess of accumulated periodic cost or income to the extent included in retail rates (a “prepaid pension asset”).

Additional information concerning pension and OPEB plans is contained in Note 11 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K. Annual net periodic benefit cost for the plans is actuarially determined using the methods and assumptions set forth in that note and is recognized ratably throughout the year. Differences between TNMP's annual net periodic costs (income) and amounts included in its regulated rates are deferred to regulatory assets or liabilities, for recovery or refund in future rate proceedings.

PNM Plans

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

	Three Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	5	$	9	$	—	$	—
Interest cost	4,036		4,985		476		613		90		123
Expected return on plan assets	(7,133)		(7,363)		(1,042)		(1,387)		—		—
Amortization of net loss	4,541		4,465		—		87		99		101
Amortization of prior service cost	—		(138)				—		—		—
Net Periodic Benefit Cost (Income)	$	1,444	$	1,949	$	(561)	$	(678)	$	189	$	224

47

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

	Nine Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	18	$	29	$	—	$	—
Interest cost	12,107		14,956		1,430		1,840		271		367
Expected return on plan assets	(21,398)		(22,089)		(3,125)		(4,161)		—		—
Amortization of net loss	13,624		13,395		—		261		296		302
Amortization of prior service cost	—		(415)		—		—		—		—
Net Periodic Benefit Cost (Income)	$	4,333	$	5,847	$	(1,677)	$	(2,031)	$	567	$	669

PNM did not make any contributions to its pension plan trust in the nine months ended September 30, 2021 and 2020 and does not anticipate making any contributions to the pension plan in 2021 through 2026 based on current law, funding requirements, and estimates of portfolio performance. Funding assumptions were developed using a discount rate of 2.9%. Actual amounts to be funded in the future will be dependent on the actuarial assumptions at that time, including the appropriate discount rate. PNM may make additional contributions at its discretion. PNM did not make any cash contributions to the OPEB trust in the nine months ended September 30, 2021 and 2020, however, a portion of the disbursements attributable to the OPEB trust are paid by PNM and are therefore considered to be contributions to the OPEB plan. Payments by PNM on behalf of the PNM OPEB plan were $1.0 million and $2.7 million for the three and nine months ended September 30, 2021 and $1.0 million and $3.1 million in the three and nine months ended September 30, 2020. These payments are expected to total $3.4 million in 2021 and $15.1 million for 2022-2026. Disbursements under the executive retirement program, which are funded by PNM and considered to be contributions to the plan, were $0.3 million and $1.1 million in the three and nine months ended September 30, 2021 and $0.3 million and $1.1 million for the three and nine months ended September 30, 2020 and are expected to total $1.3 million during 2021 and $6.0 million for 2022-2026.

TNMP Plans

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

	Three Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	12	$	12	$	—	$	—
Interest cost	435		545		77		93		4		6
Expected return on plan assets	(795)		(821)		(101)		(136)		—		—
Amortization of net (gain) loss	311		315		(81)		(81)		8		6
Amortization of prior service cost	—		—		—		—		—		—
Net Periodic Benefit Cost (Income)	$	(49)	$	39	$	(93)	$	(112)	$	12	$	12

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

	Nine Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	34	$	35	$	—	$	—
Interest cost	1,306		1,633		231		280		13		17
Expected return on plan assets	(2,386)		(2,463)		(304)		(404)		—		—
Amortization of net (gain) loss	935		944		(242)		(243)		25		18
Amortization of prior service cost	—		—		—		—		—		—
Net Periodic Benefit Cost (Income)	$	(145)	$	114	$	(281)	$	(332)	$	38	$	35

TNMP did not make any contributions to its pension plan trust in the nine months ended September 30, 2021 and 2020 and does not anticipate making any contributions to the pension plan in 2021 through 2026 based on current law, funding requirements, and estimates of portfolio performance. Funding assumptions were developed using a discount rate of 2.9%. Actual amounts to be funded in the future will depend on the actuarial assumptions at that time, including the appropriate discount rate. TNMP may make additional contributions at its discretion. TNMP did not make any contributions to the OPEB trust in the three and nine months ended September 30, 2021 and 2020 and does not expect to make contributions to the OPEB trust during the period 2021-2026. Disbursements under the executive retirement program, which are funded by TNMP and considered to be contributions to the plan, were zero in the three and nine months ended September 30, 2021 and 2020 and are expected to total $0.1 million during 2021 and $0.4 million in 2022-2026.

(11)   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 12. 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 estimable. 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, and commitments will have a material effect on its financial condition, results of operations, or cash flows.

Additional information concerning commitments and contingencies is contained in Note 16 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

Commitments and Contingencies Related to the Environment

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

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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. In August 2014, APS and the DOE entered into a settlement agreement that establishes a process for the payment of claims for costs incurred through December 31, 2019. In July 2020, APS accepted the DOE's extension of the settlement agreement for recovery of costs incurred through December 31, 2022. 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 to the extent applicable to NMPRC regulated operations.

PNM estimates that it will incur approximately $59.6 million (in 2019 dollars) for its share of the costs related to the on-site interim storage of spent nuclear fuel at PVNGS during the term of the operating licenses. PNM accrues these costs as a component of fuel expense as the nuclear fuel is consumed. At September 30, 2021 and December 31, 2020, PNM had a liability for interim storage costs of $13.0 million and $12.8 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

In 2019, the Governor signed into New Mexico state law Senate Bill 489, known as the Energy Transition Act (“ETA”). The ETA became effective as of June 14, 2019 and 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 amends the REA and 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 amends sections of the REA to allow 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. The ETA also directs the New Mexico Environmental Improvement Board to adopt standards of performance that limit CO2 emissions to no more than 1,100 lbs. per MWh beginning January 1, 2023 for new or 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 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.

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

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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 will have a significant impact on PNM’s future generation portfolio, including PNM’s planned retirement of SJGS in 2022 and the planned Four Corners exit in 2024. PNM cannot predict the full impact of the ETA or the outcome of its pending and potential future generating resource abandonment and replacement resource filings with the NMPRC. See additional discussion in Note 12 of PNM’s SJGS and Four Corners Abandonment Applications.

The Clean Air Act

Regional Haze

In 1999, EPA developed a regional haze program and regional haze rules under the CAA. The rule directs each of the 50 states to address 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. If it was demonstrated that the emissions from these sources caused or contributed to visibility impairment in any Class I area, BART must have been installed by the beginning of 2018. 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.

In 2017, EPA published revisions to the regional haze rule in the Federal Register. EPA also provided a companion draft guidance document for public comment. The new rule delayed the due date for the next cycle of SIPs from 2019 to 2021, altered the planning process that states must employ in determining whether to impose “reasonable progress” emission reduction measures, and gave new authority to federal land managers to seek additional emission reduction measures outside of the states’ planning process. Finally, the rule made several procedural changes to the regional haze program, including changes to the schedule and process for states to file 5-year progress reports. EPA’s new rule was challenged by numerous parties. On January 19, 2018, EPA filed a motion to hold the case in abeyance in light of several letters issued by EPA on January 17, 2018 to grant various petitions for reconsideration of the 2017 rule revisions. EPA’s decision to revisit the 2017 rule is not a determination on the merits of the issues raised in the petitions.

On December 20, 2018, EPA released a new guidance document on tracking visibility progress for the second planning period. EPA is allowing states discretion to develop SIPs that may differ from EPA’s guidance as long as they are consistent with the CAA and other applicable regulations. On August 20, 2019, EPA finalized the draft guidance that was released in 2016 as a companion to the regional haze rule revisions, and EPA clarified that guidance in a memorandum issued on July 8, 2021. SIPs for the second planning period were due in July 2021. 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 will retire its share of SJGS in 2022. NMED's current timeline indicates the SIP will be submitted between September 2021 and January 2022. PNM cannot predict the outcome of these matters with respect to Four Corners.

Carbon Dioxide Emissions

On August 3, 2015, EPA established standards to limit CO2 emissions from power plants. EPA took three separate but related actions in which it: (1) established the Carbon Pollution Standards for new, modified, and reconstructed power plants; (2) established the Clean Power Plan to set standards for carbon emission reductions from existing power plants; and (3) released a proposed federal plan associated with the final Clean Power Plan. The Clean Power Plan was published on October 23, 2015.

Multiple states, utilities, and trade groups filed petitions for review in the DC Circuit to challenge both the Carbon Pollution Standards for new sources and the Clean Power Plan for existing sources. Challengers successfully petitioned the US Supreme Court for a stay of the Clean Power Plan. However, before the DC Circuit could issue an opinion regarding either the Carbon Pollution Standards or the Clean Power Plan, the Trump Administration asked that the case be held in abeyance while the rule was being re-evaluated, which was granted.

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

On June 19, 2019, EPA repealed the Clean Power Plan, promulgated the ACE Rule, and revised the implementing regulations for all emission guidelines. EPA set the Best System of Emissions Reduction ("BSER") for existing coal-fired power plants as heat rate efficiency improvements based on a range of "candidate technologies" that can be applied inside the fence-line. Rather than setting a specific numerical standard of performance, EPA's rule directed states to determine which of the candidate technologies to apply to each coal-fired unit and establish standards of performance based on the degree of emission reduction achievable based on the application of BSER. On September 17, 2019, the DC Circuit issued an order that granted motions by various petitioners, including industry groups and EPA, to dismiss the cases challenging the Clean Power Plan as moot due to EPA’s issuance of the ACE Rule.

However, on January 19, 2021, the DC Circuit issued an opinion in American Lung Association and American Public Health Association v. EPA, et al. regarding challenges to the ACE Rule. The DC Circuit vacated the ACE Rule and remanded the record back to the EPA for further consideration consistent with its opinion, finding that EPA misinterpreted the CAA when it determined that the language of section 111 unambiguously barred consideration of emissions reductions options that were not applied at the source. Four petitions for writ of certiorari were filed in the U.S. Supreme Court seeking review of the DC Circuit’s January opinion vacating EPA’s repeal and replacement of the Obama Administration’s Clean Power Plan regulations for controlling carbon emissions from existing power plants. The petitioners include 1) West Virginia and 18 other states that had intervened to defend the ACE Rule, 2) North American Coal Corporation, 3) North Dakota (separately from the other states), and 4) Westmoreland Mining Holdings LLC. Several briefs were filed in support of the certiorari petitions. After receiving an extension from the DC Circuit, EPA filed its response on August 5, 2021. Briefing was completed on August 24, 2021 on the four petitions for writ.

While the DC Circuit did not uphold the ACE Rule, it did not reinstate the Clean Power Plan. EPA filed a motion seeking a partial stay of the mandate as to the repeal of the Clean Power Plan, to ensure the court’s order will not render effective the now out-of-date Clean Power Plan. On February 22, 2021, the U.S. Court of Appeals for the DC Circuit granted EPA’s motion, indicating that it would withhold issuance of the mandate with respect to the repeal of the Clean Power Plan until EPA responds to the court’s remand in a new rulemaking action. 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 the Biden Administration is unlikely to finalize the revisions proposed in 2018 and that reconsideration of the rule has concluded.

While corresponding NSR reform regulations were proposed as part of the proposed ACE Rule, the final rule did not include such reform measures. Unrelated to the ACE Rule, EPA issued a proposed rule on August 1, 2019, to clarify one aspect of the pre-construction review process for evaluating whether the NSR permitting program would apply to a proposed project at an existing source of emissions. The final rule on NSR Project Emissions Accounting became effective on December 24, 2020, clarifying that both emissions increases and decreases resulting from a project are to be considered in determining whether the proposed project will result in an increase in air emissions. The Biden Administration denied a petition for reconsideration of the rule on October 12, 2021, but indicated that it plans to initiate a new rulemaking to address the issues raised by the petitioners.

On January 27, 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.

PNM’s review of the GHG emission reductions standards that may occur as a result of legislation or regulation under the Biden Administration and in response to the court's ruling on the ACE Rule is ongoing. PNM cannot predict the impact these standards may have on its operations or a range of the potential costs of compliance, if any.

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.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOx Standard – On April 18, 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.

SO2 Standard – On May 13, 2014, EPA released the draft data requirements rule for the 1-hour SO2 NAAQS, which directs state and tribal air agencies to characterize current air quality in areas with large SO2 sources to identify maximum 1-hour SO2 concentrations. This characterization requires areas be designated as attainment, nonattainment, or unclassifiable for compliance with the 1-hour SO2 NAAQS. 

On August 11, 2015, EPA released the Data Requirements Rule for SO2, telling states how to model or monitor to determine attainment or nonattainment with the new 1-hour SO2 NAAQS.  NMED submitted the first annual report for SJGS as required by the Data Requirements Rule in June 2018. That report recommended that no further modeling was warranted due to decreased SO2 emissions. NMED submitted the second and third annual modeling report to EPA in July 2019 and July 2020. Those reports retained the recommendation that no further modeling is needed at this time and are subject to EPA review.

On February 25, 2019, EPA announced its final decision to retain, without changes, the primary health-based NAAQS for SO2. Specifically, EPA will retain 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.

On March 26, 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. This is EPA’s fourth and final set of actions to designate areas of the U.S. for the 2010 SO2 NAAQS. All areas of New Mexico have been designated attainment/unclassifiable through four rounds of designations by the EPA.

Ozone Standard – On October 1, 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. On July 13, 2020, EPA proposed to retain the existing ozone NAAQS based on a review of the full body of currently available scientific evidence and exposure/risk information. EPA finalized its decision to retain the ozone NAAQS in a notice published on December 31, 2020 making it immediately effective. The Center for Biological Diversity filed a lawsuit on February 25, 2021, challenging the decision to retain the existing ozone standard, and the Biden Administration has included the decision in its list of actions that may be reconsidered.

On November 10, 2015, EPA proposed a rule revising its Exceptional Events Rule, which outlines the requirements for excluding air quality data (including ozone data) from regulatory decisions if the data is affected by events outside an area’s control. The proposed rule is important in light of the more stringent ozone NAAQS final rule since western states like New Mexico and Arizona are subject to elevated background ozone transport from natural local sources, such as wildfires and stratospheric inversions, and transported via winds from distant sources in other regions or countries. EPA finalized the rule on October 3, 2016 and released related guidance in 2018 and 2019 to help implement its new exceptional events policy.

During 2017 and 2018, EPA released rules establishing area designations for ozone. In those rules, San Juan County, New Mexico, where SJGS and Four Corners are 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 is located in Doña Ana County, it is not located within the small area designated as non-attainment for the 2015 ozone standard. The rule became effective May 8, 2018.

On November 22, 2019, EPA issued findings that several states, including New Mexico, had failed to submit interstate transport SIPs for the 2015 8-hour ozone NAAQS. In response, in December 2019, NMED published the Public Review Draft of the New Mexico 2013 NAAQS Good Neighbor SIP that demonstrates that there are no significant contributions from New Mexico to downwind problems in meeting the federal ozone standard.

NMED has responsibility for bringing the small area in Doña Ana County designated as marginal/non-attainment for ozone into compliance and will look at all sources of NOx and volatile organic compounds. NMED has submitted the required elements for the Sunland Park Ozone Nonattainment Area SIP. This includes a transportation conformity demonstration, a 2017 baseline emissions inventory and emissions statement, and an amendment to the state's Nonattainment Permitting rules at 20.2.79 New Mexico Administrative Code to conform to EPA's SIP Requirements Rule for 2015 Q3 NAAQS (i.e., "implementation rule").

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

The SIP elements had staggered deadlines and were done in three submissions; 1) the transportation conformity demonstration was completed by the El Paso Metropolitan Planning Organization on behalf of New Mexico in 2019, which is responsible for transportation planning in that area. The submission received concurrence from EPA and the Federal Highway Administration; 2) the emissions inventory and statement SIP was submitted to EPA in September 2020; and 3) the Nonattainment New Source Review SIP was submitted to EPA on August 10, 2021.

PNM does not believe there will be material impacts to its facilities because of NMED’s 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. PNM cannot predict the outcome of this matter.

PM Standard – On January 30, 2020, EPA published in the Federal Register a notice announcing the availability of a final Policy Assessment for the Review of the NAAQS for Particulate Matter (the "Final PA"). The final assessment was prepared as part of the review of the primary and secondary PM NAAQS. In the assessment, EPA recommended lowering the primary annual PM2.5 standard to between 8 µg/m3 and 10 µg/m3. However, on April 30, 2020, EPA published a proposed rule to retain the current standards for PM due to uncertainties in the data relied upon in the Final PA. EPA accepted comments on the proposed rule through June 29, 2020. On December 7, 2020, EPA announced it will retain, without revision, the existing primary (health-based) and secondary (welfare-based) NAAQS for PM, and EPA published a notice of that final action on December 18, 2020, making it immediately effective. On January 14, 2021, several states and New York City filed a petition for review in the DC Circuit, challenging EPA’s final rule retaining the current primary and secondary PM NAAQS. On February 9, 2021, a similar lawsuit was filed by the Center for Biological Diversity in the DC Circuit. On June 10, 2021, EPA announced that it will reconsider the previous administration’s December 2020 decision to retain the current primary and secondary PM NAAQS and on October 8, 2021, EPA announced the release of a new draft policy assessment (the "Draft PA"). Like the Final PA, the Draft PA states that available scientific evidence and technical information indicate that the current standards may not be adequate to protect public health and welfare, as required by the Clean Air Act. EPA anticipates issuing a proposed rule in summer 2022 and a final rule in spring 2023.

Navajo Nation Environmental Issues

Four Corners is located on the Navajo Nation and is held under easements granted by the federal government, as well as agreements with the Navajo Nation which grant each of the owners the right to operate on the site. The Navajo Acts purport to give the Navajo Nation Environmental Protection Agency authority to promulgate regulations covering air quality, drinking water, and pesticide activities, including those activities that occur at Four Corners. In October 1995, the Four Corners participants filed a lawsuit in the District Court of the Navajo Nation challenging the applicability of the Navajo Acts to Four Corners. In May 2005, APS and the Navajo Nation signed an agreement resolving the dispute regarding the Navajo Nation’s authority to adopt operating permit regulations under the Navajo Nation Air Pollution Prevention and Control Act. As a result of this agreement, APS sought, and the court granted, dismissal of the pending litigation in the Navajo Nation Supreme Court and the Navajo Nation District Court, to the extent the claims relate to the CAA. The agreement does not address or resolve any dispute relating to other aspects of the Navajo Acts. PNM cannot currently predict the outcome of these matters or the range of their potential impacts.

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 SJGS and Four Corners, seven options for meeting Best Technology Available (“BTA”) standards for reducing impingement. SJGS has a closed-cycle recirculating cooling system, which is a listed BTA and may also qualify for the “de minimis rate of impingement” based on the design of the intake structure. 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 determination. Compliance deadlines under the rule are tied to permit renewal and will be subject to a schedule of compliance established by the permitting authority.

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

The rule is not clear as to how it applies and what the compliance timelines are for facilities like SJGS that have a cooling water intake structure and only a multi-sector general stormwater permit. However, EPA has indicated that it is contemplating a December 31, 2023 compliance deadline. PNM is working with EPA regarding this issue and does not expect material changes as a result of any requirements that may be imposed upon SJGS, particularly given the NMPRC's April 1, 2020 approval for PNM to retire its share of SJGS by June 2022.

On May 23, 2018, several environmental groups sued EPA Region IX in the United States Court of Appeals for the Ninth Circuit Court 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 on June 12, 2018. The permit did not contain conditions related to the cooling water intake structure rule as EPA determined that the facility has achieved BTA for both impingement and entrainment by operating a closed-cycle recirculation system. On July 16, 2018, 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 several requirements under the Clean Water Act and did not contain required provisions concerning certain revised effluent limitation guidelines, existing-source regulations governing cooling-water intake structures, and effluent limits for surface seepage and subsurface discharges from coal-ash disposal facilities. On December 19, 2018, EPA withdrew the Four Corners NPDES permit in order to examine issues raised by the environmental groups. Withdrawal of the permit moots the appeal pending before the EAB. EAB thereafter dismissed the environmental groups’ appeal. EPA issued an updated NPDES permit on September 30, 2019. The permit was once again appealed to the EAB and was stayed before the effective date. Oral argument was heard on September 3, 2020. The EAB issued an order denying the petition for review on September 30, 2020. The denial was based on the EAB's determination that the petitioners had failed to demonstrate that review of the permit was warranted on any of the grounds presented in the petition. 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 and will expire on November 30, 2025. 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 Circuit. The September 2019 permit remains in effect pending this appeal. PNM cannot predict whether there will be further appeals of this matter or whether the outcome of any such appeal will have a material impact on PNM’s financial position, results of operations or cash flows.

Effluent Limitation Guidelines

On June 7, 2013, EPA published proposed revised wastewater effluent limitation guidelines establishing technology-based wastewater discharge limitations for fossil fuel-fired electric power plants.  EPA signed the final Steam Electric Effluent Limitation Guidelines rule on September 30, 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 Effluent Limitation Guidelines rule was challenged in the U.S. Court of Appeals for the Fifth Circuit by numerous parties. On April 12, 2017, EPA signed a notice indicating its intent to reconsider portions of the rule, and on August 22, 2017, 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. On April 12, 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.

On September 18, 2017, EPA published a final rule for postponement of certain compliance dates. The rule postponed the earliest date on which compliance with the Effluent Limitation Guidelines for these waste streams would be required from November 1, 2018 until November 1, 2020. On November 22, 2019, EPA published a proposed rule revising the original Effluent Limitation Guidelines while maintaining the compliance dates. Comments were due January 21, 2020. On October 13, 2020, EPA published in the Federal Register the final Steam Electric Effluent Limitation Guidelines 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 rule will require compliance with new limits as soon as possible on or after October 13, 2021, but no later than December 31, 2025.

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(Unaudited)

Because SJGS is zero discharge for wastewater and is not required to hold a NPDES permit, it is expected that minimal to no requirements will be imposed. Reeves Station discharges cooling tower blowdown to a publicly owned treatment plant and holds an NPDES permit. It is expected that minimal to no requirements will be imposed at Reeves Station.

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 in 2023. 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 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 December 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 March 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 in October 2019. 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.

PNM submitted work plans to NMED in January 2021 for review and approval. PNM is prepared to commence work shortly after receiving NMED approval.

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 are currently disposed of in the surface mine pits adjacent to the plant. SJGS does not operate any 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 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 final coal ash rule, which became effective on October 19, 2015, included a non-hazardous waste determination for coal ash and sets minimum criteria for existing and new CCR landfills and surface impoundments. On December 16, 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 contains a number of provisions related to the CCR rules. Among other things, the WIIN Act allows, but does not require, states to develop and submit CCR permit programs for EPA approval, provides flexibility for states to incorporate EPA’s final rule for CCRs or develop other criteria that are at least as protective as EPA’s final rule, and requires EPA to approve state permit programs within 180 days of submission by the state. Because states are not required to

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(Unaudited)

implement their own CCR permit programs, EPA will implement the permit program in states that choose not to implement a program, subject to Congressional funding. Until permit programs are in effect, EPA has authority to directly enforce the CCR rule. 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. There is no timeline for establishing either state or federal permitting programs.

On July 30, 2018, EPA published a rule that constitutes “Phase One, Part One” of its ongoing reconsideration and revision of the April 17, 2015 CCR rule. The final Phase One, Part One rule includes two types of revisions. The first revision 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. This deadline was again 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.

On August 14, 2019, EPA published a second round of revisions, which are commonly referred to as the “Phase Two” revisions. Phase Two proposed revisions to reporting and accessibility to public information, the "CCR piles" and "beneficial use" definitions and the requirements for management of CCR piles. EPA has reopened and extended the Phase Two comment several times. Most recently, on March 12, 2021, EPA reopened the comment period on its prior notice that announced the availability of new information and data pertaining to the Phase Two proposed rule. EPA extended the comment period for an additional 60 days, until May 11, 2021. EPA has not yet finalized provisions in Phase Two related to beneficial use of CCR and CCR piles. It is anticipated EPA will issue proposed and final rules addressing these issues in 2022.

Since promulgating its Phase Two proposal, EPA has finalized two other rules addressing various CCR rule provisions. On December 2, 2019, 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 CCR Rule, Part A also proposed changing the classification of compacted soil-lined or clay-lined surface impoundments from “lined” to “unlined”. In addition, Part A delineated a process for owners/operators to submit requests for alternative closure deadlines based on lack of alternate disposal capacity. EPA issued the final Part A on August 28, 2020, which became effective on September 28, 2020. This rule finalized the classification of soil-lined and clay-lined surface impoundments as unlined, thus, triggering closure or retrofit requirements for those impoundments. The final Part A also gave operators of unlined impoundments until April 11, 2021 to cease receipt of waste at these units and initiate closure.

On March 3, 2020, EPA issued the proposed Holistic Approach to Closure Part B ("Part B"), which delineated the process for owners/operators to submit alternate liner demonstrations for clay-lined surface impoundments that could otherwise meet applicable requirements. Part B also proposed regulations addressing beneficial use for closure of surface impoundments. On November 12, 2020, EPA issued the final Part B rule, which became effective December 14, 2020. This rule did not include beneficial use of CCR for closure, which EPA explains will be addressed in subsequent rulemaking actions. EPA intends to issue several other rulemakings covering legacy ponds and finalizing parts of previously proposed rules. These proposed rules and final rules are expected in 2022.

On February 20, 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. The deadline to provide comments was extended to August 7, 2020. The final rule is expected in January 2022. PNM cannot predict the outcome of EPA’s rule making activity or the outcome of any related litigation, and whether or how such a ruling would affect operations at Four Corners.

The CCR rule does not cover mine placement of coal ash. OSM is expected to publish a proposed rule covering mine placement in the future and will likely be influenced by EPA’s rule and the determination by EPA that CCRs are non-hazardous. 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. Based upon the requirements of the final Part A CCR rule, PNM conducted a CCR assessment at SJGS and made minor modifications at the plant to ensure that there are no facilities that would be considered impoundments or landfills under the rule. PNM would seek recovery from its retail customers of all CCR costs for jurisdictional assets that are ultimately incurred.

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(Unaudited)

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 will need corrective action or will need to cease operations and initiate closure by April 11, 2021. As part of this assessment, Four Corners will continue to gather additional groundwater data and perform remedial evaluations. 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

SJGS

The coal requirements for SJGS are supplied by WSJ LLC. In addition to coal delivered to meet the current needs of SJGS, PNM has prepaid the current San Juan mine owner and operator, WSJ LLC, for certain coal mined but not yet delivered to the plant site. At September 30, 2021 and December 31, 2020, prepayments for coal, which are included in other current assets, amounted to $21.9 million and $26.3 million. Additional information concerning the coal supply for SJGS is contained in Note 16 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

In conjunction with the activities undertaken to comply with the CAA for SJGS, PNM and the other owners of SJGS evaluated alternatives for the supply of coal to SJGS. On July 1, 2015, PNM and Westmoreland entered into a new coal supply agreement (the “SJGS CSA”), pursuant to which Westmoreland, through its indirectly wholly-owned subsidiary SJCC, agreed to supply all of the coal requirements of SJGS through June 30, 2022. PNM and Westmoreland also entered into agreements under which CCR disposal and mine reclamation services for SJGS would be provided. As discussed in Note 6, WSJ LLC assumed the rights and obligations of SJCC under the SJGS CSA and the agreements for CCR disposal and mine reclamation services.

Pricing under the SJGS CSA is primarily fixed, with adjustments to reflect changes in general inflation. The pricing structure takes into account that WSJ LLC has been paid for coal mined but not delivered. PNM has provided notice to Westmoreland that PNM does not intend to extend the term of the SJGS CSA or to negotiate a new coal supply agreement for SJGS, which will result in the current agreement expiring on its own terms on June 30, 2022. See additional discussion of PNM’s SJGS Abandonment Application in Note 12.

WSJ LLC notified PNM in mid-July that it had encountered unfavorable geologic conditions that were impeding longwall progress in the San Juan Mine. On August 17, 2021, WSJ LLC issued a formal notice of non-normal conditions due to WSJ LLC’s inability to maintain a reserve of coal at required levels. WSJ LLC also notified PNM that these geologic complications constituted a force majeure event that was preventing WSJ LLC from satisfying its obligation to maintain required coal inventory levels. Although geologic conditions are reportedly improving, PNM does not know whether reduced levels of coal inventory may continue until normal conditions recur in the longwall panel or whether the period of non-normal conditions will impact full load operations through the remainder of the year.

The SJGS RA sets forth terms under which PNM acquired the coal inventory, including coal mined but not delivered, of the exiting SJGS participants as of January 1, 2016, and supplied coal to the SJGS exiting participants for the period from January 1, 2016 through December 31, 2017, and is supplying coal to the SJGS remaining participants over the term of the SJGS CSA. Coal costs under the SJGS CSA are significantly less than under the previous arrangement with SJCC. Since substantially all of PNM’s coal costs are passed through the FPPAC, the benefit of the reduced costs is passed through to PNM’s customers.

In connection with certain mining permits relating to the operation of the San Juan mine, the San Juan mine owner 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 the San Juan mine owner, PNMR entered into the WFB LOC Facility under which letters of credit aggregating $30.3 million have been issued. As discussed in Note 6, on March 15, 2019, the assets owned by SJCC were sold to WSJ LLC, a subsidiary of Westmoreland Mining Holdings, LLC. Under the sale agreement, WSJ LLC assumed the rights and obligations of SJCC including obligations to PNMR under the outstanding letters of credit.

Four Corners

APS purchases all of Four Corners’ coal requirements from NTEC, an entity owned by the Navajo Nation, under the

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(Unaudited)

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. PNM's share of the coal costs is being recovered through the FPPAC. In connection with the exit of Four Corners, PNM would make payments of $75.0 million to NTEC for relief from its obligations under the coal supply agreements for Four Corners after December 31, 2024. PNM is not proposing to recover the $75.0 million from ratepayers and, if approved as filed, would not be recovered through the FPPAC. See Note 12 for additional information on PNM's Four Corners Abandonment Application. See additional discussion of the Four Corners CSA in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

NTEC has contracted with Bisti Fuels Company, LLC, a subsidiary of The North American Coal Corporation, for management and operation of the mine. Under the CSA, NTEC has the right after a specified period to request approval from the Four Corners owners to replace Bisti Fuels Company as mine manager with NTEC’s internal resources and perform all or some mine management functions. APS granted approval on behalf of the owners on June 16, 2021, subject to certain credit assurance requirements. On June 17, 2021, NTEC notified The North American Coal Corporation that the contract mining agreement between Bisti Fuels Company and NTEC is terminated effective September 30, 2021. NTEC assumed direct operations at Navajo Mine on October 1, 2021.

Coal Mine Reclamation

As indicated under Coal Combustion Residuals Waste Disposal above, SJGS currently disposes of CCRs in the surface mine pits adjacent to the plant and Four Corners disposes of CCRs in ponds and dry storage areas. As discussed in Note 16 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K, in conjunction with the proposed shutdown of SJGS Units 2 and 3 to comply with the BART requirements of the CAA, periodic updates to the coal mine reclamation study were requested by the SJGS participants. These updates have generally increased PNM's share of the estimated cost of mine reclamation and have included adjustments to reflect the December 2017 shutdown of SJGS Units 2 and 3, the terms of the reclamation services agreement with WSJ LLC, and changes to reflect the requirements of the 2015 San Juan mine permit plan.

In late 2020, a mine reclamation cost study was completed for the mine that serves SJGS and in December 2020, PNM remeasured its liability, which resulted in an increase in the overall reclamation costs of $3.6 million, due primarily to higher inflationary factors. As a result, PNM recorded a less than $0.1 million decrease in the liability at December 31, 2020 related to the underground mine and a decrease to the regulatory assets on the Condensed Consolidated Balance Sheets and recorded a $3.6 million increase in the liability associated with the surface mine as regulatory disallowances and restructuring costs on the Condensed Consolidated Statements of Earnings. 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 then 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.

A coal mine reclamation study for the mine that serves Four Corners was issued in 2019. The study reflected operation of the mine through 2031, the term of the Four Corners CSA. The study resulted in a net increase in PNM’s share of the coal mine reclamation obligation of $0.8 million, which was primarily driven by lower overhead costs offset by an increase driven by a reduction in the discount rate used by PNM to measure the liability during the year ended December 31, 2019. As discussed in Note 12, PNM remains responsible for its share of costs associated with mine reclamation under the Four Corners Purchase and Sale Agreement with NTEC. NTEC and PNM will complete a reclamation study in 2024 providing the final mine reclamation cost estimate on the date of ownership transfer. PNM will make its final reclamation payment to NTEC based on the reclamation study in 2024 and will have no further obligations regarding the mine reclamation after 2024. PNM determined that events and circumstances regarding Four Corners, including the Four Corners Purchase and Sale Agreement with NTEC and the Four Corners Abandonment Application, indicated that it is more likely than not that PNM’s share of Four Corners coal mine reclamation obligation would be settled in 2024, rather than 2031. As of December 31, 2020, PNM remeasured its Four Corners coal mine reclamation liability and recorded a decrease to the liability of $2.5 million on the Condensed Consolidated Balance Sheet and a decrease to regulatory disallowances and restructuring costs on the Condensed Consolidated Statement of Earnings.

Based on the most recent estimates, PNM’s remaining payments as of September 30, 2021, for mine reclamation, in future dollars, are estimated to be $75.4 million for the surface mines at both SJGS and Four Corners and $35.1 million for the underground mine at SJGS. At September 30, 2021 and December 31, 2020, liabilities, in current dollars, of $68.3 million and $71.7 million for surface mine reclamation and $27.5 million and $26.1 million for underground mine reclamation were recorded in other deferred credits.

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(Unaudited)

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. The SJGS owners entered into a reclamation trust funds agreement to provide funding to compensate WSJ LLC for post-term reclamation obligations. As discussed in Note 16 of the Notes to the Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K, as part of the restructuring of SJGS ownership, the SJGS owners negotiated the terms of an amended agreement to fund post-term reclamation obligations under the CSA. 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 periodically deposit funds into the reclamation trust for the owner’s share of the mine reclamation obligation. Deposits, which are based on funding curves, must be made on an annual basis. As part of the restructuring of SJGS ownership discussed above, the SJGS participants agreed to adjusted interim trust funding levels. PNM funded $3.2 million in 2020 and, based on PNM’s reclamation trust fund balance at September 30, 2021, the current funding curves indicate PNM’s required contributions to its reclamation trust fund would be $4.8 million in 2021, $6.2 million in 2022, and zero in 2023.

Under the Four Corners CSA, PNM is required to fund its ownership 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 $2.0 million in 2020 and $2.2 million in 2021, and anticipates providing additional funding of $2.1 million in each of the years from 2022 through 2024. As discussed above, under the terms of the Four Corners Purchase and Sale Agreement with NTEC, PNM will make its final reclamation payment to NTEC based on the reclamation study in 2024 and will have no further obligations regarding the mine reclamation.

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 2018 Compliance Filing and its SJGS and Four Corners Abandonment Applications in Note 12. PNM is currently unable to determine the outcome of these matters or the range of possible impacts.

Continuous Highwall Mining Royalty Rate

In August 2013, the DOI Bureau of Land Management (“BLM”) issued a proposed rulemaking that would retroactively apply the surface mining royalty rate of 12.5% to continuous highwall mining (“CHM”).  Comments regarding the rulemaking were due on October 11, 2013, and PNM submitted comments in opposition to the proposed rule. There is no legal deadline for adoption of the final rule.

SJCC, as former owner and operator of San Juan mine, utilized the CHM technique from 2000 to 2003, and with the approval of the Farmington, New Mexico Field Office of BLM to reclassify the final highwall as underground reserves, applied the 8.0% underground mining royalty rate to coal mined using CHM and sold to SJGS.  In March 2001, SJCC learned that the DOI Minerals Management Service (“MMS”) disagreed with the application of the underground royalty rate to CHM.  In August 2006, SJCC and MMS entered into an agreement tolling the statute of limitations on any administrative action to recover unpaid royalties until BLM issued a final, non-appealable determination as to the proper rate for CHM-mined coal.  The proposed BLM rulemaking has the potential to terminate the tolling provision of the settlement agreement. Underpaid royalties of approximately $5 million for SJGS would become due if the proposed BLM rule is adopted as proposed.  PNM’s share of any amount that is ultimately paid would be approximately 46.3%, none of which would be passed through PNM’s FPPAC. PNM is unable to predict the outcome of this matter.

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. In accordance with this act, the PVNGS participants are insured against public liability exposure for a nuclear incident up to $13.5 billion per occurrence. PVNGS maintains the maximum available nuclear liability insurance in the amount of $450 million, which is provided by American Nuclear Insurers. The remaining $13.1 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. Based on PNM’s 10.2% interest in each of the three PVNGS units, as of September 30, 2021, PNM’s maximum potential retrospective premium assessment per incident for all three units is $42.1 million, with a maximum annual payment limitation of $6.2 million, to be adjusted periodically for inflation.

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(Unaudited)

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 $5.4 million for each retrospective premium assessment declared by NEIL’s Board of Directors due to losses. The insurance coverages discussed in this and the previous paragraph are subject to certain policy conditions, sublimits, and exclusions.

PVNGS Water Supply Litigation

In 1986, an action commenced regarding the rights of APS and the other PVNGS participants to the use of groundwater and effluent at PVNGS. APS filed claims that dispute the court’s jurisdiction over PVNGS’ groundwater rights and their contractual rights to effluent relating to PVNGS and, alternatively, seek confirmation of those rights. In 1999, the Arizona Supreme Court issued a decision finding that certain groundwater rights may be available to the federal government and Native American tribes. In addition, the Arizona Supreme Court issued a decision in 2000 affirming the lower court’s criteria for resolving groundwater claims. Litigation on these issues has continued in the trial court. No trial dates have been set in these matters. PNM does not expect that this litigation will have a material impact on its results of operation, financial position, or cash flows.

San Juan River Adjudication

In 1975, the State of New Mexico filed an action in NM District Court to adjudicate all water rights in the San Juan River Stream System, including water used at Four Corners and SJGS. PNM was made a defendant in the litigation in 1976. In March 2009, then President Obama signed legislation confirming a 2005 settlement with the Navajo Nation. Under the terms of the settlement agreement, the Navajo Nation’s water rights would be settled and finally determined by entry by the court of two proposed adjudication decrees.  The court issued an order in August 2013 finding that no evidentiary hearing was warranted in the Navajo Nation proceeding and, on November 1, 2013, issued a Partial Final Judgment and Decree of the Water Rights of the Navajo Nation approving the proposed settlement with the Navajo Nation. A number of parties subsequently appealed to the New Mexico Court of Appeals. PNM entered its appearance in the appellate case and supported the settlement agreement in the NM District Court. On April 3, 2018, the New Mexico Court of Appeals issued an order affirming the decision of the NM District Court. Several parties filed motions requesting a rehearing with the New Mexico Court of Appeals seeking clarification of the order, which were denied. The State of New Mexico and various other appellants filed a writ of certiorari with the NM Supreme Court. The NM Supreme Court granted the State of New Mexico’s petition and denied the other parties’ requests. The issues regarding the Navajo Nation settlement have been briefed and are awaiting a decision by the NM Supreme Court. Adjudication of non-Indian water rights is ongoing.

PNM is participating in this proceeding since PNM’s water rights in the San Juan Basin may be affected by the rights recognized in the settlement agreement and adjudicated to the Navajo Nation, which comprise a significant portion of water available from sources on the San Juan River and in the San Juan Basin and which have priority in times of shortages. PNM is unable to predict the ultimate outcome of this matter or estimate the amount or range of potential loss and cannot determine the effect, if any, of any water rights adjudication on the present arrangements for water at SJGS and Four Corners. Final resolution of the case cannot be expected for several years. An agreement reached with the Navajo Nation in 1985, however, provides that if Four Corners loses a portion of its rights in the adjudication, the Navajo Nation will provide, for an agreed upon cost, sufficient water from its allocation to offset the loss.

Navajo Nation Allottee Matters

In September 2012, 43 landowners filed a notice of appeal with the Bureau of Indian Affairs (“BIA”) appealing a March 2011 decision of the BIA Regional Director regarding renewal of a right-of-way for a PNM transmission line. The landowners claim to be allottees, members of the Navajo Nation, who pursuant to the Dawes Act of 1887, were allotted ownership in land carved out of the Navajo Nation and allege that PNM is a rights-of-way grantee with rights-of-way across the allotted lands and are either in trespass or have paid insufficient fees for the grant of rights-of-way or both.  The allottees generally allege that they were not paid fair market value for the right-of-way, that they were denied the opportunity to make a showing as to their view of fair market value, and thus denied due process. The allottees filed a motion to dismiss their appeal with prejudice, which was granted in April 2014. Subsequent to the dismissal, PNM received a letter from counsel on behalf of what appears to be a subset of the 43 landowner allottees involved in the appeal, notifying PNM that the specified allottees were revoking their consents for renewal of right of way on six specific allotments.  On January 22, 2015, PNM received a letter from the BIA Regional Director identifying ten allotments with rights-of-way renewals that were previously contested. The

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(Unaudited)

letter indicated that the renewals were not approved by the BIA because the previous consent obtained by PNM was later revoked, prior to BIA approval, by the majority owners of the allotments. It is the BIA Regional Director’s position that PNM must re-obtain consent from these landowners. On July 13, 2015, PNM filed a condemnation action in the NM District Court regarding the approximately 15.49 acres of land at issue. On September 18, 2015, the allottees filed a separate complaint against PNM for federal trespass. On December 1, 2015, the court ruled that PNM could not condemn two of the five allotments at issue based on the Navajo Nation’s fractional interest in the land. PNM filed a motion for reconsideration of this ruling, which was denied. On March 31, 2016, the Tenth Circuit granted PNM’s petition to appeal the December 1, 2015 ruling. Both matters have been consolidated. Oral argument before the Tenth Circuit was heard on January 17, 2017. On May 26, 2017, the Tenth Circuit affirmed the district court. On July 8, 2017, PNM filed a Motion for Reconsideration en banc with the Tenth Circuit, which was denied. The NM District Court stayed the case based on the Navajo Nation’s acquisition of interests in two additional allotments and the unresolved ownership of the fifth allotment due to the owner’s death. On November 20, 2017, PNM filed its petition for writ of certiorari with the US Supreme Court, which was denied. The underlying litigation continues in the NM District Court. On March 27, 2019, several individual allottees filed a motion for partial summary judgment on the issue of trespass. The Court held a hearing on the motion on June 18, 2019, and took the motion under advisement. The parties have reached an agreement in principle. The parties are negotiating the specific terms of the settlement documents. PNM cannot yet determine the outcome of these matters.

Merger-Related Litigation

Six purported shareholders of PNMR filed lawsuits against PNMR and the members of the Board challenging the proposed Merger with Avangrid. The lawsuits all challenged the adequacy of the disclosures in the definitive proxy statement filed by PNMR with the SEC on January 5, 2021, and sought, among other things, to enjoin the Merger or, if the Merger has been consummated, to rescind the Merger or an award of damages, and an award of attorneys’ and experts’ fees and expenses. Five of the lawsuits were filed in the United States District Court for the Southern District of New York and one was filed in the United States District Court for the Eastern District of New York. The lawsuits pending in the Southern District of New York were consolidated in the case captioned In re PNM Resources, Inc. Shareholder Litigation, Consolidated Civil Action No. 1:20-CV-10874. The five plaintiffs in the consolidated action in the Southern District of New York filed notices of voluntary dismissal, and, on April 9, 2021, the Court ordered the Clerk of Court to close the consolidated action and all member cases. All five cases filed in the Southern District of New York have been closed. The case pending in the Eastern District of New York, captioned Durlacher v. PNM Resources, Inc., et al., Case No. 1:21-cv-0024, was not served on the defendants and the plaintiff filed a notice of voluntary dismissal on February 15, 2021. These matters are now concluded.

Texas Winter Storm

In mid-February 2021, Texas experienced a severe winter storm delivering the coldest temperatures in 100 years for many parts of the state. As a result, the ERCOT market was not able to deliver sufficient generation load to the grid resulting in significant, statewide outages as ERCOT directed transmission operators to curtail thousands of firm load megawatts. TNMP complied with ERCOT directives to curtail the delivery of electricity in its service territory and did not experience significant outages on its system outside of the ERCOT directed curtailments. Various regulatory and governmental entities are conducting, or have announced they may conduct, inquiries, investigations and other reviews of the Texas winter storm event. Entities that have announced that they plan to conduct or are conducting such inquiries, investigations and other reviews include FERC, NERC, Texas Reliability Entity Inc., ERCOT, the Texas Legislature, the Texas Attorney General, the PUCT, and the Galveston County District Attorney. Further, lawsuits have been filed against various market participants relating to the power outages resulting from the Texas winter storm, including TNMP. As a utility operating during the Texas winter storm event, there is a risk TNMP could be named in additional lawsuits in the future. TNMP intends to vigorously defend itself against any claims raised. TNMP has deferred bad debt expense from defaulting REPs to a regulatory asset totaling $0.8 million at September 30, 2021, and will seek recovery in a general rate case. At this time, the Company does not expect significant financial impacts related to this event, however, it cannot predict the outcome of such matters or the impact on the ERCOT market.

(12)   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 11. Additional information concerning regulatory and rate matters is contained in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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(Unaudited)

PNM

Renewable Portfolio Standard

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 RCT for the procurement of renewable resources to prevent excessive costs being added to rates. The ETA sets a RCT of $60 per MWh 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 a rate rider. See Renewable Energy Rider below.

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 current capacity of 11 MW

•Solar distributed generation, aggregating 190.8 MW at September 30, 2021, owned by customers or third parties from whom PNM purchases any net excess output and RECs

Renewable Energy Rider

The NMPRC has authorized PNM to recover certain renewable procurement costs through a rate rider billed on a per KWh basis. In its 2020 renewable energy procurement plan, which became effective on January 1, 2021, PNM proposed to collect $67.8 million for the year. The NMPRC approved recovery of $65.5 million through the rider, reflecting the rejection of PNM's request to recover the $2.3 million Sky Blue regulatory asset in 2021. PNM recorded revenues from the rider of $13.0 million and $44.4 million in the three and nine months ended September 30, 2021, and $12.0 million and $42.3 million in the three and nine months ended September 30, 2020. On June 1, 2021 PNM filed its renewable energy procurement plan for 2022 which proposes to collect $66.9 million for the year. PNM is not proposing any new procurements in the plan but is proposing to retire a small number of RECs in 2022 from resources that have not been previously approved as part of the RPS plan. The NMPRC assigned this matter to a hearing examiner and a hearing was held on September 30, 2021. On October 15, 2021, NMPRC Staff and PNM jointly filed the post-hearing brief stating that pending issues to the case had been resolved with PNM agreeing to certain compliance provisions. On October 20, 2021, the hearing examiner issued an order regarding briefing and exceptions stating that the forthcoming recommended decision should be uncontroversial and time offered for exceptions will likely be minimal.

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 did not exceed such limitation in 2020.

Energy Efficiency and Load Management

Program Costs and Incentives/Disincentives

The New Mexico Efficient Use of Energy Act (“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 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 not exceed seventy-five thousand dollars.

In 2019, PNM submitted a filing to address incentives to be earned in 2020. PNM’s proposed incentive mechanism was similar to that approved for 2018 and 2019 with minor modifications to reflect input from interested parties. The proposed incentive mechanism includes a base incentive of 7.1% of program costs, or approximately $1.8 million, based on savings of 59

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(Unaudited)

GWh in 2020 with a sliding scale that provides for additional incentive if savings exceed 68 GWh. No hearings were considered necessary and PNM’s 2020 energy efficiency rider reflecting the 2020 incentive became effective beginning December 30, 2019. On April 15, 2021 PNM filed its 2020 Energy Efficiency Annual Report which reconciles the actual 2020 profit incentive collections with the profit incentive authorized by the NMPRC resulting in an additional $0.8 million incentive to be collected during the remainder of 2021. The additional incentive was authorized for 2020 because annual energy savings for the year exceeded 87 GWh, and was the maximum level of profit incentive allowed under the approved mechanism. PNM began collecting the additional incentive effective May 27, 2021.

On April 15, 2020, PNM filed an application for energy efficiency and load management programs to be offered in 2021, 2022, and 2023. The proposed program portfolio consists 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 application also sought approval of 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 proposed incentive would increase if PNM is able to achieve savings greater than 80 GWh in a year. The application also proposed an advanced metering infrastructure (“AMI”) pilot program, which included the installation of 5,000 AMI meters at a cost of $2.9 million. PNM proposed the pilot program to comply with an NMPRC order denying PNM’s February 2016 application to replace its existing customer metering equipment with AMI. PNM did not recommend the AMI pilot program due to the limited benefits that are cost-effective under a pilot structure. On September 17, 2020, the hearing examiner in the case issued a recommended decision recommending that PNM's proposed energy efficiency and load management program be approved, with the exception of the proposed AMI pilot program. On October 28, 2020, the NMPRC issued an order adopting the recommended decision 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. PNM proposed to record the difference between the annual revenue per customer derived from the cost of service approved in the NM 2015 Rate Case and the annual revenue per customer actually recovered from the rate classes beginning on January 1, 2021. If approved, on January 1, 2022, PNM would begin to collect the difference from customers if the revenue per customer from the NM 2015 Rate Case exceeds the actual revenue recovered in 2021, or return the difference to customers if the actual revenue per customer recovered in 2021 exceeds the revenue per customer from the NM 2015 Rate Case. 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 allege that PNM’s proposed rate adjustment mechanism is inconsistent with the EUEA. Responses to the motions to dismiss were filed on August 7, 2020. On September 16, 2020, ABCWUA, Bernalillo County, CCAE, the City of Albuquerque, NEE, NMAG, NMPRC Staff ("Staff") and WRA filed testimony. CCAE and WRA support PNM's petition, but recommend that the rate adjustment mechanism not take effect until new rates are approved in PNM's next general rate case. The other parties filing testimony oppose PNM's petition. 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 November 24, 2020, the NMAG requested that the NMPRC deny both petitions for declaratory orders and instead address disincentives under the EUEA in a rulemaking. On March 17, 2021, the NMPRC issued an order granting the petitions for declaratory order, commencing a declaratory order proceeding to address the petitions, denying the NMAG’s request to initiate a rulemaking, and appointing a hearing examiner to preside over the declaratory order proceeding. Initial briefs were filed on June 7, 2021 and response briefs were filed on June 28, 2021. Oral arguments were made on July 15, 2021. PNM cannot predict the outcome of this matter.

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 four years of that period.

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(Unaudited)

2020 IRP

NMPRC rules required PNM to file its 2020 IRP in July 2020. On March 16, 2020, PNM filed a motion to extend the deadline to file its 2020 IRP to six months after the NMPRC issues a final order approving a replacement resource portfolio and closes the docket in the bifurcated SJGS Abandonment Application and replacement resource proceedings. On April 8, 2020, the NMPRC approved PNM's motion to extend the deadline to file its 2020 IRP as requested. On January 29, 2021, PNM filed its 2020 IRP addressing the 20-year planning period from 2020 through 2040. The plan focuses on a carbon-free electricity portfolio by 2040 that would eliminate coal at the end of 2024. This includes replacing the power from San Juan with a mix of approved carbon-free resources and the plan to exit Four Corners at the end of 2024. The plan highlights the need for additional investments in a diverse set of resources, including renewables to supply carbon-free power, energy storage to balance supply and demand, and efficiency and other demand-side resources to mitigate load growth. On May 24, 2021, the hearing examiner issued a procedural schedule and required PNM, upon request, to provide modeling data and assumptions to parties within two weeks. Additionally, PNM is required upon request, to run modeling or provide reasonable access to PNM virtual machines at PNM's expense. The alternative modeling deadline concluded on August 30, 2021 and Staff's recommendation is due on November 11, 2021.

Abandonment Applications made under the ETA

As discussed in Note 11, the 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 also 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 the qualifying utility.

SJGS Abandonment Application

On July 1, 2019, PNM filed a Consolidated Application for the Abandonment and Replacement of SJGS and Related Securitized Financing Pursuant to the ETA (the “SJGS Abandonment Application”). The SJGS Abandonment Application sought NMPRC approval to retire PNM’s share of SJGS after the existing coal supply and participation agreements end in June 2022, for approval of replacement resources, and for the issuance of approximately $361 million of energy transition bonds (the “Securitized Bonds”). PNM’s request for the issuance of Securitized Bonds included approximately $283 million of forecasted undepreciated investments in SJGS at June 30, 2022, an estimated $28.6 million for plant decommissioning and coal mine reclamation costs, approximately $9.6 million in upfront financing costs, and approximately $20.0 million for job training and severance costs for affected employees. Proceeds from the Securitization Bonds would also be used to fund approximately $19.8 million for economic development in the four corners area.

On July 10, 2019, the NMPRC issued an order requiring the SJGS Abandonment Application be considered in two proceedings: one addressing SJGS abandonment and related financing and the other addressing replacement resources. After multiple filings, proceedings, requests for clarification and legal challenges, on January 29, 2020, the NM Supreme Court issued a ruling requiring the NMPRC to apply the ETA to all aspects of PNM’s SJGS Abandonment Application, indicating any previous NMPRC orders inconsistent with the ruling should be vacated, and denying parties’ request for stay. The NM Supreme Court issued a subsequent opinion, on July 23, 2020, more fully explaining the legal rationale for the January 29, 2020 ruling. Hearings on the abandonment and securitized financing proceedings were held in December 2019 and hearings on replacement resources were held in January 2020.

On February 21, 2020, the hearing examiners issued two recommended decisions recommending approval of PNM’s proposed abandonment of SJGS, subject to approval of replacement resources, and approval of PNM’s proposed financing order to issue Securitized Bonds.  The hearing examiners recommended that PNM be authorized to abandon SJGS by June 30, 2022, and to record regulatory assets for certain other abandonment costs that are not specifically addressed under the provisions of the ETA to preserve its ability to recover the costs in a future general rate case. The hearing examiner recommended that this authority only extend to the deferral of the costs and it not be an approval of any ratemaking treatment. The hearing examiners also recommended PNM be authorized to issue Securitized Bonds of up to $361 million and establish an Energy Transition Charge. The hearing examiners recommended an interim rate rider adjustment upon the start date of the Energy Transition Charge to provide immediate credits to customers for the full value of PNM’s revenue requirement related to SJGS until those reductions are reflected in base rates. In addition, the hearing examiners recommended PNM be granted authority to establish regulatory assets to recover costs that PNM will pay prior to the issuance of the Securitized Bonds,

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(Unaudited)

including costs associated with the bond issuances as well as for severances, job training, economic development, and workforce training. On April 1, 2020, the NMPRC unanimously approved the hearing examiners' recommended decisions regarding the abandonment of SJGS and the related securitized financing under the ETA.

On April 10, 2020, CFRE and NEE filed a notice of appeal with the NM Supreme Court of the NMPRC's approval of PNM's request to issue securitized financing under the ETA. The NM Supreme Court granted motions to intervene filed by PNM, WRA, CCAE, and the Sierra Club. On May 8, 2020, CFRE and NEE filed a joint statement of issues with the NM Supreme Court which asserts that the NMPRC improperly applied the ETA and that the ETA violates the New Mexico Constitution. On June 19, 2020, WRA filed a motion to dismiss CFRE and NEE’s constitutional challenges to the ETA on the ground that the New Mexico Constitution provides that only New Mexico district courts have original jurisdiction over the claims. On July 24, 2020, the NM Supreme Court issued an order denying WRA’s motion to dismiss. On August 17, 2020, the appellants filed a Brief in Chief and on October 5, 2020, PNM, WRA, CCAE and Sierra Club filed Answer Briefs. PNM cannot predict the outcome of this matter.

PNM evaluated the consequences of the NMPRC's April 1, 2020 orders approving the abandonment of SJGS and the related issuance of Securitized Bonds. This evaluation indicated that it is probable that PNM will be required to fund severances for PNM employees at the facility upon its retirement in 2022 and for PNMR shared services employees providing administrative and other support services to SJGS. In addition, the evaluation indicated that it is probable PNM will be obligated to fund severances and other costs for the WSJ LLC employees and to fund certain state agencies for economic development and workforce training upon the issuance of the Securitized Bonds. As a result, in March 2020, PNMR and PNM recorded obligations of $9.4 million and $8.1 million for estimated severances, $8.9 million for obligations to fund severances and other costs of WSJ LLC employees, and to fund $19.8 million to state agencies for economic development and workforce training upon the issuance of the Securitized Bonds. The total amount recorded for these estimates of $38.1 million and $36.8 million is reflected in other deferred credits and as a corresponding deferred regulatory asset on PNMR's and PNM's Condensed Consolidated Balance Sheets at December 31, 2020. These estimates may be adjusted in future periods as the Company refines its expectations. In addition, as discussed above these costs may be challenged by parties pursuant to the notices of appeal filed with the NM Supreme Court on April 10, 2020.

On June 24, 2020, the hearing examiners issued a recommended decision on PNM's request for approval of replacement resources that addressed the entire portfolio of replacement resources, which superseded a previous partial recommended decision issued on March 27, 2020. The hearing examiners concluded that the ultimate selection of a portfolio of replacement resources involves policy considerations that are the province of the NMPRC and stated that they did not intend to make that decision for the NMPRC. On July 29, 2020, the NMPRC issued an order approving resource selection criteria identified in the ETA and would include PPAs for 650 MW of solar and 300 MW of battery storage. The order also granted in part PNM’s request for an extension of time for PNM to file the application to implement the replacement resource portfolio. PNM had 60 days from the date of the order to file an application in a separate docket seeking approval of the proposed final, executed contracts, for any replacement resources that are not currently in evidence that have been approved by the NMPRC.

On September 28, 2020, PNM filed its application for approval of the final executed contracts for the replacement resources. In addition, PNM provided updated cost estimates of $8.1 million for the SJGS replacement resources, based on the NMPRC authorization to create regulatory assets granted in the abandonment order, which it plans to seek recovery of in a future general rate case. On November 13, 2020, the hearing examiner issued a recommended decision recommending approval of a 200 MW solar PPA combined with a 100 MW battery storage agreement and a 100 MW solar PPA combined with a 30 MW battery storage agreement. On December 2, 2020, the NMPRC issued an order adopting the recommended decision in its entirety. On May 24, 2021, PNM filed a notice that informed the NMPRC that a solar PPA for 100 MW with battery storage of 30 MW, which was approved as a replacement resources for SJGS, will not be completed in time to serve PNM’s load during the 2022 summer peak season. On July 22, 2021, PNM filed notice to the NMPRC that as a result of supply chain delays, two additional approved replacement resource projects will not be fully completed in time to serve load during the 2022 summer peak season. Specifically, a 200 MW solar PPA with battery storage of 100 MW will only have 50 MW of available capacity in June 2022 and then ramp up through the summer and fall, and a 300 MW solar PPA with battery storage of 150 MW will initially have only 150 MW of solar and 150 MW of battery storage available in June 2022 and is planned to ramp up to full capacity in September 2022. PNM's existing resources, including available reserves, may have been insufficient for 2022 summer peak load reliability considering these delays. As a result, PNM entered into three agreements to purchase power from third parties in the third quarter to ensure customer demand during the 2022 summer peak load period is met; the purchase of 85 MW, unit contingent from Four Corners for June through September of 2022; the purchase of 150 MW, firm power in June and September 2022; and the purchase of 40 MW, unit contingent from PVNGS Unit 3 for the full year of 2022.

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(Unaudited)

Additional information concerning the SJGS Abandonment Application is contained in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

Four Corners Abandonment Application

On November 1, 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. The sale is contingent upon NMPRC approval and expected to close by the end of 2024. 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. Pursuant to the Four Corners Purchase and Sale Agreement, PNM will retain its current plant decommissioning and coal mine reclamation obligations, subject to the final mine reclamation study and payment at the end of 2024. PNM will have no obligation for reclamation after 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 would make a final payment of $60.0 million. The initial $15.0 million payment was recorded in other current assets on the Consolidated Balance Sheet as of December 31, 2020.

On January 8, 2021, PNM filed the Four Corners Abandonment Application, which seeks NMPRC approval to exit PNM’s share of Four Corners as of December 31, 2024, and to issue approximately $300 million of energy transition bonds as provided by the ETA. PNM’s request for the issuance of Securitized Bonds included approximately $272 million of forecasted undepreciated investments in Four Corners at December 31, 2024, an estimated $4.6 million for plant decommissioning costs, estimated $7.3 million in upfront financing costs, and estimated $16.5 million in economic development. PNM intends to submit a separate application for NMPRC approval of a replacement resource portfolio following NMPRC action on this application.

On January 26, 2021, Sierra Club filed a motion in the Four Corners Abandonment Application requesting that the NMPRC order PNM to file supplemental testimony addressing the prudence of Four Corners investments or alternatively that the NMPRC dismiss the Four Corners Abandonment Application and permit PNM to refile after the prudence issue is resolved. In addition, on January 28, 2021, NEE and CFRE filed a motion requesting that the NMPRC dismiss the application, stating that approval of the abandonment would be contrary to the provision of the REA that prevents the sale of carbon dioxide emitting electricity-generating resources as a means of complying with the RPS, and that the Four Corners Abandonment Application does not demonstrate that the sale of 200 MW to NTEC will not result in a net detriment to public interest. On February 26, 2021, the hearing examiner issued an order on the sufficiency of the Four Corners Application finding that the application was deficient on its face and failed to adequately support whether or not the sale and transfer of PNM’s interest in Four Corners to NTEC is in the public interest. However, given the NMPRC’s preference to address Four Corners issues in the case, as well as PNM’s concession on filing an amended application, the hearing examiner did not recommend that the case be dismissed. The order required PNM to file an amended application by March 15, 2021; established that the nine-month period for review of the amended application shall start on the date of PNM’s filing of the amended application and run through December 15, 2021; required PNM to file supplemental testimony addressing the prudence of its investment in Four Corners; required PNM to more explicitly address the statutory standards for approval of the proposed transfer to NTEC; and required PNM to file a motion to withdraw the January 8, 2021 Four Corners Application. On March 15, 2021, PNM filed an amended application and supplemental testimony for the approval of the abandonment and transfer of Four Corners and issuance of a financing order pursuant to the ETA and a motion to withdraw the January 8, 2021 Four Corners Application. The amended application and supplemental testimony provided additional information to support PNM's request to abandon its interest in Four Corners and transfer that interest to NTEC, and also provided additional detail explaining how the proposed sale and abandonment provides a net public benefit. A hearing began August 31, 2021, briefs were filed October 1, 2021 and response briefs were filed October 13, 2021.

On May 17, 2021 NEE and CFRE ("Joint Movants") again filed motions to dismiss the case, providing reasons which include; PNM's failure to disclose the reason for the divestiture in the plant is the Merger; the application is deficient because PNM has failed to produce the seasonal operation agreement with the other Four Corners owners; and reiterated their prior view that PNM's amended application is contrary to the REA. Also on May 17, 2021, CCAE filed a motion to dismiss the case stating that PNM's application is devoid of any discussion of the assumption of liabilities by NTEC pertaining to PNM's share of Four Corners. On May 18, 2021, San Juan Citizens Alliance/Dine Care and the Native American Voters Alliance Education Project ("NAVAEP") filed a joinder supporting CCAE's motion. On June 1, 2021, PNM filed responses to the Joint Movants' and CCAE motions to dismiss and filed a motion to strike portions of the Joint Movants' and CCAE's motions to dismiss. PNM's motion states that the Joint Movants and CCAE rely upon materials beyond the pleadings in the case and within the

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record in other proceedings to support their motions. On June 14, 2021 the hearing examiner issued an order denying the motions to dismiss from NEE, CFRE and CCAE.

On October 30, 2020, NEE filed a formal complaint with the NMPRC seeking an investigation into the reasonableness and lawfulness of PNM’s continued reliance on “climate-altering and uneconomic coal” at Four Corners. NEE explained that they withdrew their Supreme Court appeal of the NM 2016 Rate Case under the notion that PNM would be filing a rate case in 2019 and they would be able to challenge the Four Corners expenditures in that case. NEE explained that because PNM has delayed its rate case several times, Four Corners has remained “imprudently” in rates. NEE asked that PNM be required to demonstrate that PNM’s investment in Four Corners was prudent. NEE stated if the NMPRC deems PNM’s investment as imprudent, ratepayers will be held harmless and all costs including carrying charges, effective October 30, 2020, and going forward, be denied. On February 10, 2021, the NMPRC denied NEE’s complaint and stated that issues related to Four Corners prudence should be addressed in the Four Corners Abandonment Application. On February 22, 2021, NEE filed a Motion for Reconsideration of the NMPRC’s February 10, 2021 order, which was denied on March 10, 2021. On April 9, 2021, NEE filed a Notice of Appeal with the NM Supreme Court regarding their formal complaint on Four Corners. On July 6, 2021, NEE filed a motion to withdraw its Notice of Appeal with the NM Supreme Court. On September 21, 2021 the NM Supreme Court issued its order granting NEE's motion to withdraw its appeal; the court also issued a mandate to the NMPRC to take further action as might be needed consistent with the order.

The financial impact of an early exit of Four Corners and the NMPRC approval process are influenced by many factors outside of PNM’s control, including the overall political and economic conditions of New Mexico. See additional discussion of the ETA in Note 11. PNM cannot predict the outcome of these matters.

PVNGS Leased Interest Abandonment Application

On April 2, 2021, PNM filed an application with the NMPRC requesting approval for the decertification and abandonment of 114 MW of leased PVNGS capacity, sale and transfer of related assets, and approval to procure new resources ("PVNGS Leased Interest Abandonment Application"). As discussed in Note 13, PNM currently controls leased capacity in PVNGS Unit 1 and Unit 2 under five separate leases ("Leased Interest") that were approved and certificated by the predecessor agency to the NMPRC in the 1980s. Four of the five leases for 104 MW of Leased Interest terminate on January 15, 2023, while the remaining lease for 10 MW of Leased Interest terminates on January 15, 2024. Associated with the Leased Interest are certain PNM-owned assets and nuclear fuel that are necessary for the ongoing operation and maintenance of the Leased Interest and integration of the Leased Interest generation to the transmission network. PNM has determined that there will be net benefits to its customers to return the Leased Interest to the lessors in conformity with the leases, sell and transfer the related PNM-owned assets, and to replace these Leased Interest with new resources. In the application PNM is requesting NMPRC authorization to decertify and abandon its Leased Interest and to create regulatory assets for the associated remaining undepreciated investments with consideration of cost recovery of the undepreciated investments in a future rate case. PNM is also seeking NMPRC approval to sell and transfer the PNM-owned assets and nuclear fuel supply associated with the Leased Interest to SRP, which will be acquiring the Leased Interest from the lessors upon termination of the existing leases. In addition, PNM is seeking NMPRC approval for a 150 MW solar PPA combined with a 40 MW battery storage agreement, and a stand-alone 100 MW battery storage agreement to replace the Leased Interest. To ensure system reliability and load needs are met in 2023, when a majority of the leases expire, PNM is also requesting NMPRC approval for a 300 MW solar PPA combined with a 150 MW battery storage agreement. PNM's application sought a six-month regulatory time frame. On April 21, 2021, the NMPRC issued an order assigning a hearing examiner and stated PNM's request to abandon the Leased Interest does not have any statutory or rule time limitation and the six-month limit in which the NMPRC must issue an order regarding the request for approvals of the solar PPAs and battery storage agreements does not begin until after the NMPRC acts on the abandonment request. On June 14, 2021 and June 25, 2021 PNM filed supplemental testimony responding to questions provided by the hearing examiner. On June 28, 2021, NEE and CCAE jointly filed a motion to dismiss a portion of the application claiming that since PNM's request to abandon the Leased Interest was filed after PNM had already provided irrevocable notice it would not acquire the Leased Interest, abandonment is no longer required. On July 28, 2021, the hearing examiner issued a recommended decision on NEE's and CCAE's joint motion to dismiss, recommending dismissal of PNM's requests for approval to abandon and decertify the Leased Interest; dismissal of PNM's request for approval to sell and transfer the related assets; and dismissal of PNM's request to create regulatory assets for the associated remaining undepreciated investments, but does not preclude PNM seeking recovery of the costs in a general rate case in which the test year period includes the time period in which PNM incurs such costs. The hearing examiner's recommended decision further provides that PNM's request for replacement and system reliability resources should remain within the scope of this case. On August 25, 2021, the NMPRC issued an order granting portions of the July 28, 2021 recommended decision that were not contested related to dismissal of PNM's request for approval to abandon and decertify the Leased Interest and dismissal of PNM's request for approval to sell and transfer the related assets. In addition, the order bifurcated the issue of approval for the two PPAs and three

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battery storage agreements into a separate docket so it may proceed expeditiously. On September 8, 2021 the NMPRC issued an order on the remaining issues in the recommended decision. The order found that PNM's request for a regulatory asset to record costs associated with obtaining an abandonment order should be dismissed. However, the requests for regulatory assets associated with the remaining undepreciated investments should be addressed at an evidentiary hearing. On September 20, 2021, ABCWUA, Bernalillo County, NEE and the NMAG filed a joint motion to reconsider the September 8, 2021 NMPRC order. Also, on September 20, 2021, PNM filed a motion for rehearing of the September 8, 2021 order stating that certain requirements of the order would lead to compromising PNM's First Amendment rights. On October 6, 2021, the NMPRC issued an order granting the motions for reconsideration and vacated the September 8, 2021 order, without specifically addressing issues raised in the motions. A hearing on the two PPAs and three battery storage agreements is scheduled for November 11, 12 and 15, 2021.

In addition to approval by the NMPRC, PNM and SRP requires NRC approval for the transfer of the associated possessory licenses at the end of the term of each of the respective leases. PNM cannot predict the outcome of this matter.

Facebook, Inc. Data Center Project

PNM has a special service contract to provide service to Facebook, Inc. for a data center being constructed in PNM’s service area. Facebook’s service requirements include the acquisition by PNM of a sufficient amount of new renewable energy resources and RECs to match the energy and capacity requirements of the data center. The cost of renewable energy procured is passed through to Facebook under a rate rider. A special service rate is applied to Facebook’s energy consumption in those hours of the month when their consumption exceeds the energy production from the renewable resources. As of September 30, 2021, PNM is procuring energy from 130 MW of solar-PV capacity from NMRD, a 50% equity method investee of PNMR Development. See additional discussion of NMRD in Note 16.

PNM has NMPRC approval for several PPAs to purchase renewable energy and RECs to supply renewable energy to the data center. Details related to these PPAs can be found in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

On February 8, 2021, PNM filed an application with the NMPRC for approval to service the data center for an additional 190 MW of solar PPA combined with 100 MW of battery storage and a 50 MW solar PPA expected to be operational in 2023. On April 28, 2021, the NMPRC issued an order finding that a hearing will be held with a hearing examiner presiding. On June 16, 2021 a hearing was held by the NMPRC with closing statements filed on June 21, 2021. On June 23, 2021, the NMPRC issued an Order for Continuance, stating concerns with the proposed addendum to the special service contract and its methodology for calculating a credit to Facebook for the capacity supplied by the 100 MW battery storage agreement. To address these concerns the Order required PNM and Facebook to renegotiate the addendum to the special service contract and the battery storage agreement. Additionally, the NMPRC designated a mediator to the facilitate the negotiations. PNM was ordered to file a renegotiated modification to its application by July 14, 2021 with responses from other parties due July 21, 2021. On July 6, 2021, PNM filed a Motion for Rehearing stating that the NMPRC's June 23, 2021 Order for Continuance contains substantive issues including misstatement of facts presented during the hearing on PNM’s application, which must be amended or withdrawn on rehearing. PNM’s motion also pointed out procedural issues with the order, including requiring mediation with Facebook who is not a party to the case while not including Staff, who is the only party to disagree with PNM’s application; and requiring PNM and Facebook to agree to modifications of the special service contract with which they are not in agreement, are not part of the application, and has not been vetted at hearing. On July 7, 2021, the NMPRC designated mediator issued a report cancelling the schedule mediation because PNM and Facebook were not willing to participate. On July 14, 2021, the NMPRC issued an order granting PNM's Motion for Rehearing and scheduling a further public hearing for July 23, 2021. The NMPRC vacated the public hearing in response to Facebook’s inability to provide a witness to testify at the hearing. On July 28, 2021, the NMPRC issued a final order reversing the order granting a rehearing; approved the solar PPAs for 190 MW and 50 MW; approved only 50 MW of the requested 100 MW battery storage; and rejected the proposed addendum to the special service contract and its methodology for calculating a credit to Facebook for the capacity supplied by the battery storage. On October 1, 2021, in compliance with the final order, PNM filed a Notice of Filing Amendments recognizing that the battery storage is 50 MW instead of 100 MW and PPA and battery storage requirements for approval of the addendum to the special service contract is waived. This matter is now concluded.

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(Unaudited)

COVID-19 Regulatory Matters

In March 2020, PNM and other utilities voluntarily implemented a temporary suspension of disconnections and late payment fees for non-payment of utility bills in response to the impacts of the novel coronavirus global pandemic (“COVID-19”). On March 18, 2020, the NMPRC conducted an emergency open meeting for the purpose of adopting emergency amendments to its rules governing service to residential customers. The NMPRC’s emergency order is applicable during the duration of the Governor of New Mexico's emergency executive order and allowed for the closure of payment centers, prohibited the discontinuance of a residential customer’s service for non-payment, and suspends the expiration of medical certificates for certain customers. On April 27, 2020, PNM, El Paso Electric Company, New Mexico Gas Company, and Southwestern Public Service Company filed a joint motion with the NMPRC requesting authorization to track costs resulting from each utility's response to the COVID-19 outbreak. The utilities proposed these incremental costs and uncollected customer accounts receivable resulting from COVID-19 during the period March 11, 2020 through December 31, 2020, be recorded as a regulatory asset. On June 24, 2020, the NMPRC issued an order authorizing all public utilities regulated by the NMPRC to create a regulatory asset to defer incremental costs related to COVID-19, including increases to bad debt expense incurred during the period beginning March 11, 2020 through the termination of the Governor of New Mexico’s emergency executive order. The NMPRC order requires public utilities creating regulatory assets to pursue all federal, state, or other subsidies available, to record a regulatory liability for all offsetting cost savings resulting from the COVID-19 pandemic, and allows PNM to request recovery in future ratemaking proceedings. As a result, PNM has deferred incremental costs related to COVID-19 of $13.2 million and $8.8 million in regulatory assets on the Condensed Consolidated Balance Sheet at September 30, 2021 and December 31, 2020. In addition, PNM has costs savings related to COVID-19 of $0.9 million in regulatory liabilities on the Condensed Consolidated Balance Sheet at September 30, 2021 and December 31, 2020. The NMPRC’s order also imposed additional quarterly reporting requirements on public utilities creating regulatory assets that include changes in customer usage and increased costs and savings recorded to regulatory assets and liabilities.

On February 3, 2021, the NMPRC issued an order finding that the temporary mandatory moratorium on disconnections of residential utility customers shall be in effect from the date of the order for 100 days, which ended May 14, 2021. At the end of the moratorium, the 90-day transition period began, which continued the temporary moratorium on disconnections to provide the utilities additional time to assist residential customers with arrearages to enter into installment agreements. On July 14, 2021, the NMPRC issued an order clarifying previous orders that the mandatory requirements of the NMPRC's previous order prohibiting residential disconnects should be voluntarily complied with by investor-owned utilities until August 12, 2021. PNM began disconnections at the end of the transition period.

Transportation Electrification Program

On December 18, 2020, in compliance with New Mexico Statute, PNM filed its PNM 2022-2023 Transportation Electrification Program (“TEP”) for approval with the NMPRC. PNM’s requested TEP includes a budget of approximately $8.4 million with flexibility of 25%. As proposed, up to 25% of the program budget will be dedicated to low and moderate income customers and is based on a model with no company ownership of charging facilities. PNM’s proposed TEP provides incentives through rebates to both residential and non-residential customers towards the purchase of chargers and/or behind-the-meter infrastructure. PNM’s TEP includes a request for a modified rate to add an electric vehicle pilot with a time-of-use option, a new non-residential electric vehicle time-of-use rate pilot without demand charges and implementation of a new rider to collect the actual costs of the TEP. PNM’s application requested NMPRC approval by the end of August 2021 and authority to file a new TEP by the end of June 2023. A hearing was held the week of May 24, 2021. On August 30, 2021 the hearing examiner issued a recommended decision approving, among other things, PNM's budget flexibility proposal, PNM's proposed pilot time-of-use rate and PNM's TEP Rider. Exceptions to the recommended decision were filed on September 24, 2021. PNM cannot predict the outcome of this matter.

Unexecuted Transmission Service Agreements (TSAs) with Leeward Renewable Energy

On March 12, 2021, PNM filed four unexecuted TSAs with FERC totaling 145 MW with Leeward Energy. The unexecuted TSAs provide long-term firm, point-to-point transmission service on PNM’s transmission system. The unexecuted TSAs are based on the pro-forma transmission service agreements with certain non-conforming provisions under Attachment A of PNM’s OATT and include PNM’s OATT rate. PNM is filing the unexecuted TSAs at the request of Leeward because the parties have been unable to reach an agreement on the terms and conditions for transmission service. In particular, Leeward believes the rate under the unexecuted TSAs should be an incremental rate while PNM believes the appropriate rate is its OATT rate.

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(Unaudited)

On April 2, 2021, Leeward Energy and Pattern Energy separately protested PNM’s March 12, 2021 filing of four unexecuted TSAs with Leeward Energy. The parties are requesting that FERC direct PNM to apply the same rate to the unexecuted TSAs as the incremental rate assessed to the Western Spirit transmission facilities, inclusive of Leeward’s network upgrades and requested service, or, in the alternative, initiate hearing and settlement judge procedures to address the unjust and unreasonable application of the FERC’s “higher of” policy. On April 19, 2021, PNM filed a motion for leave to answer and contested the arguments made by Leeward Energy and Pattern Energy. In its response, PNM stated that it disagrees with the parties' pricing scheme because doing so would not recognize all the transmission facilities necessary to provide Leeward service, does not hold PNM's other transmission customers harmless, and is inconsistent with FERC pricing policy and precedent. PNM further explained that the proposal to include its FERC approved embedded rate in the unexecuted TSAs is just and reasonable and should be accepted by FERC. On May 11, 2021, FERC issued an order accepting PNM's four unexecuted TSAs. In the order, FERC stated that it agreed with PNM's pricing scheme and agreed that PNM's proposal to use the OATT rate will ensure that the benefit of Leeward's addition to the system will be spread among other existing system users, rather than simply transferred to Pattern. On June 10, 2021, Pattern and Leeward both filed a request for rehearing of the FERC Order. On September 10, 2021, Leeward filed a petition in the United States District Court for the District of Columbia for review of FERC's order accepting PNM's four unexecuted TSAs. PNM cannot predict the outcome of this matter.

FERC Compliance

PNM is conducting 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. PNM anticipates it will pursue any applicable waivers with FERC upon completion of PNM’s internal review. PNM is unable to predict the outcome of this matter.

The Community Solar Act

On June 18, 2021, Senate Bill 84, known as the Community Solar Act, became effective. The Community Solar Act establishes a program that allows for the development of community solar facilities and provides customers of a qualifying utility with the option of accessing solar energy produced by a community solar facility in accordance with the Community Solar Act. The NMPRC is charged with administering the Community Solar Act program, establishing a total maximum capacity of 200 MW community solar (applicable until November 2024) facilities and allocating proportionally to the New Mexico electric investor-owned utilities and participating cooperatives. As required under the Community Solar Act, the NMPRC opened a docket on May 12, 2021 to adopt rules to establish a community solar program no later than April 1, 2022. On June 15, 2021, the NMPRC issued an order which required utilities provide a notice to all future applicants and to any likely applicants that, until the effective date of the NMPRC's rules in this area the NMPRC's existing interconnection rules and manual remain in place until amended or replaced by the NMPRC, and further, that a place in a utility's applicant queue for interconnection does not and will not provide any advantage for selection as a community solar project. PNM has provided the required notices. On October 27, 2021, the NMPRC adopted an order issuing a Notice of Proposed Rulemaking starting the formal process for adoption of rules pursuant to the Community Solar Act. PNM cannot predict the full impact of the Community Solar Act or the outcome of the NMPRC's rulemaking.

San Juan Generating Station Unit 1 Outage

On June 30, 2021, a cooling tower used for SJGS Unit 1 failed resulting in a unit outage. SJGS Unit 1 was brought back online on July 25, 2021. PNM anticipates the damages to the facility will be reimbursed under an existing property insurance policy that covers SJGS, subject to a deductible of $2.0 million. PNM’s exposure to the cost of repairs is $1.0 million, reflecting PNM’s 50% ownership interest in SJGS Unit 1. On July 14, 2021, the NMPRC issued an order opening a formal docket and inquiry into the cooling tower incident. PNM has responded to a number of NMPRC questions in the inquiry, including questions about the cause of the cooling tower failure, cost and progress of the cleanup and remediation, whether customers experienced loss of service, how PNM provided power during the outage, safety practices and procedures at SJGS, and the history of inspections on the cooling towers. PNM cannot predict the outcome of this matter.

TNMP

Recovery of TNMP Rate Case Costs

Recovery of the cost of TNMP’s rate case was moved into a separate proceeding to begin after the conclusion of the TNMP 2018 Rate Case discussed in the 2020 Annual Reports on Form 10-K. TNMP sought recovery of costs incurred through August 2019 in the amount of $3.8 million and proposed these costs be collected from customers over a three-year period. In

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(Unaudited)

October 2019, TNMP and other parties to the proceedings filed an unopposed settlement stipulation that reduced TNMP’s cost recovery to $3.3 million and provide for recovery over a period not to exceed three-years beginning on March 1, 2020. On January 16, 2020, the PUCT approved the settlement. As a result of the PUCT's order, TNMP recorded a pre-tax write-off of $0.5 million in December 2019.

Transmission Cost of Service Rates

TNMP can update its transmission cost of service (“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. 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)
October 7, 2020	$	10.8	$	2.0
March 12, 2021	$	112.6	$	14.1
September 20, 2021	$	41.2	$	6.3

Periodic Distribution Rate Adjustment

PUCT rules permit interim rate adjustments to reflect changes in investments in distribution assets. Distribution utilities may file for a periodic rate adjustment between April 1 and April 8 of each year as long as the electric utility is not earning more than its authorized rate of return using weather-normalized data.

On April 6, 2020, TNMP filed its 2020 DCOS that requested an increase in TNMP's annual distribution revenue requirement of $14.7 million based on net incremental rate base of $149.2 million. On June 26, 2020, the parties filed a unanimous settlement for a $14.3 million annual distribution revenue requirement with rates effective September 1, 2020. On August 13, 2020, the PUCT approved the unanimous settlement. On April 5, 2021, TNMP filed its 2021 DCOS that requested an increase in TNMP annual distribution revenue requirement of $14.0 million based on an increase in rate base of $104.5 million. On July 1, 2021, TNMP reached a unanimous settlement agreement with parties that would authorize TNMP to collect an increase in annual distribution revenues of $13.5 million beginning in September 2021. Subsequently, the ALJ issued an order on July 9, 2021 approving interim rates effective September 1, 2021, and remanded the case to the PUCT for approval. On September 23, 2021, the PUCT approved substantially all costs in the unanimous settlement.

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 and over collected costs from prior years, rate case expenses, and performance bonuses (if programs exceed mandated savings goals). TNMP’s 2019 EECRF filing requested recovery of $5.9 million, including a performance bonus of $0.8 million, and became effective on March 1, 2020. TNMP’s 2020 EECRF filing requested recovery of $5.9 million, including a performance bonus of $1.0 million, and became effective on March 1, 2021. On May 27, 2021, TNMP filed its request to adjust the EECRF to reflect changes in costs for 2022. The total amount requested was $7.2 million, which includes a performance bonus of $2.3 million based on TNMP's energy efficiency achievements in the 2020 plan year. On July 28, 2021, a unanimous stipulation and settlement was filed with the PUCT to recover its requested costs in 2022, including the performance bonus of $2.3 million. On October 7, 2021, the PUCT approved TNMP's energy efficiency application.

COVID-19 Electricity Relief Program

On March 26, 2020, the PUCT issued an order establishing an 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 ensure these customers continued to have electric service. In addition, the program provided transmission and distribution providers access to zero-interest loans from ERCOT. Collectively, ERCOT’s loans could not exceed $15 million. The program had a term of six months unless extended by the PUCT. In a separate order, the PUCT authorized

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(Unaudited)

electric utilities to establish a regulatory asset for costs related to COVID-19. These costs included but were not limited to costs related to unpaid accounts.

TNMP filed its rider on March 30, 2020. The rider was effective immediately and established a charge of $0.33 per MWh in accordance with the PUCT's order. Final collections under the rider exceeded unpaid residential retail customer bills and were presented net as a regulatory liability of $0.1 million on the Condensed Consolidated Balance Sheet as of December 31, 2020. Other COVID-19 related costs of $0.9 million and $0.7 million were also recorded as a regulatory asset on the Condensed Consolidated Balance Sheet as of September 30, 2021 and December 31, 2020. On April 14, 2020, TNMP executed an interest-free loan agreement to borrow $0.5 million from ERCOT and on October 30, 2020, the balance of the loan was repaid.

On August 27, 2020, the PUCT issued an order determining that new enrollments in the program should end on August 31, 2020, and benefits under the program should end on September 30, 2020, to allow eligible customers a minimum of one month of benefits from the program. All requests for reimbursement were made by November 30, 2020. On December 4, 2020, TNMP filed to end collections under the tariff. Final collections under the rider were made on December 11, 2020. On January 14, 2021, TNMP made a final compliance filing for the electricity relief program.

Advanced Meter System Deployment

TNMP was notified by its largest AMS service provider that its existing communication platform would be decommissioned in February 2022. TNMP evaluated technological alternatives for its AMS and on October 2, 2020, filed an application with the PUCT for authorization to implement necessary upgrades of approximately $46 million by November 2022. On January 14, 2021, the PUCT approved TNMP's application, TNMP will seek recovery of the investment associated with the upgrade in a future general rate proceeding or distribution cost recovery factor filing.

AMS Reconciliation

On July 14, 2021, TNMP filed a request with the PUCT to consider and approve its final reconciliation of the costs spent on the deployment of AMS from April 1, 2018 through December 31, 2018 of $9.0 million and approve appropriate carrying charges until full collection. On September 13, 2021, the PUCT Staff filed a recommendation for approval of TNMP's application for substantially all costs from April 1, 2018 through December 31, 2018.

(13)     Lease Commitments

The Company leases office buildings, vehicles, and other equipment. In addition, PNM leases interests in PVNGS Units 1 and 2 and certain rights-of-way agreements are classified as leases. All of the Company's leases with terms in excess of one year are recorded on the balance sheet 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 Condensed Consolidated Statements of Earnings.

See additional discussion of the Company's leasing activities in Note 8 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

PVNGS

PNM leases interests in Units 1 and 2 of PVNGS. The PVNGS leases were entered into in 1985 and 1986 and initially were scheduled to expire on January 15, 2015 for the four Unit 1 leases and January 15, 2016 for the 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 now expire on January 15, 2023 and the one Unit 2 lease now expires on January 15, 2024. The annual lease payments during the renewal periods aggregate $16.5 million for PVNGS Unit 1 and $1.6 million for Unit 2.

The terms of each of the extended leases do not provide for additional renewal options beyond their currently scheduled expiration dates. PNM had the option to purchase the assets underlying each of the extended leases at their fair market value or to return the lease interests to the lessors on the expiration dates. On June 11, 2020, PNM provided notice to the lessors and the

73

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NMPRC of its intent to return the assets underlying both the PVNGS Unit 1 and Unit 2 leases upon their expiration in January 2023 and 2024. Although PNM elected to return the assets underlying the extended leases, PNM retains certain obligations related to PVNGS, including costs to decommission the facility. PNM is depreciating its capital improvements related to the extended leases using NMPRC approved rates through the end of the NRC license period for each unit, which expire in June 2045 for Unit 1 and in June 2046 for Unit 2. On April 5, 2021, PNM and SRP entered into an Asset Purchase and Sale Agreement, pursuant to which PNM agreed to sell to SRP certain PNM-owned assets and nuclear fuel necessary to the ongoing operation and maintenance of leased capacity in PVNGS Unit 1 and Unit 2, which SRP has agreed to acquire from the lessors upon termination of the existing leases. The proposed transaction between PNM and SRP is subject to receipt by PNM of approval by the NMPRC and PNM and SRP require NRC approval for the transfer of the associated possessory licenses at the end of the term of each of the respective leases. If the proposed transaction is not consummated, PNM may be required to retain all or a portion of its currently leased capacity in PVNGS or be exposed to other claims for damages by the lessors. PNM will seek to recover its undepreciated investments, as well as any other obligations related to PVNGS from NM retail customers. See PVNGS Leased Interest Abandonment Application discussion in Note 12.

PNM is exposed to loss under the PVNGS lease arrangements upon the occurrence of certain events that PNM does not consider reasonably likely to occur. Under certain circumstances (for example, the NRC issuing specified violation orders with respect to PVNGS or the occurrence of specified nuclear events), PNM would be required to make specified payments to the lessors and take title to the Leased Interests. If such an event had occurred as of September 30, 2021, amounts due to the lessors under the circumstances described above would be up to $148.4 million, payable on January 15, 2022 in addition to the scheduled lease payments due on that date.

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 2021 payment for the amount due under the Navajo Nation right-of-way lease was $7.3 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 Condensed Consolidated Balance Sheets and recognizes amortization expense associated with these agreements in the Condensed Consolidated Statement of Earnings over their term. As of September 30, 2021 and December 31, 2020, the unamortized balance of these rights-of-ways was $54.0 million and $55.8 million. PNM recognized amortization expense associated with these agreements of $0.9 million and $2.8 million in the three and nine months ended September 30, 2021 and $0.9 million and $2.8 million in the three and nine months ended September 30, 2020.

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 September 30, 2021, residual value guarantees on fleet vehicle and equipment leases are $0.8 million, $1.5 million, and $2.3 million for PNM, TNMP, and PNMR Consolidated.

74

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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

	September 30, 2021						December 31, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating leases:
Operating lease assets, net of amortization	$	79,808	$	5,778	$	85,956	$	97,461	$	7,206	$	105,133
Current portion of operating lease liabilities	26,166		1,988		28,230		25,130		2,193		27,460
Long-term portion of operating lease liabilities	51,233		3,579		55,106		75,941		4,779		81,065

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 Condensed Consolidated Balance Sheets is presented below:

	September 30, 2021						December 31, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Financing leases:
Non-utility property	$	14,276	$	15,722	$	30,328	$	11,453	$	13,299	$	25,055
Accumulated depreciation	(3,838)		(4,185)		(8,185)		(2,044)		(2,241)		(4,383)
Non-utility property, net	10,438		11,537		22,143		9,409		11,058		20,672
Other current liabilities	2,620		2,897		5,602		1,993		2,397		4,470
Other deferred credits	7,639		8,649		16,373		7,176		8,669		15,972

Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities as of September 30, 2021 is presented below:

	PNM		TNMP		PNMR Consolidated
Weighted average remaining lease term (years):
Operating leases	5.83		3.08		5.65
Financing leases	4.31		4.35		4.32
Weighted average discount rate:
Operating leases	3.99	%	3.97	%	3.98	%
Financing leases	2.62	%	2.72	%	2.67	%

75

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Information for the components of lease expense is as follows:

	Three Months Ended September 30, 2021						Nine Months Ended September 30, 2021
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating lease cost:	$	6,569	$	594	$	7,192	$	20,020	$	1,880	$	22,006
Amounts capitalized	(199)		(517)		(716)		(645)		(1,618)		(2,264)
Total operating lease expense	6,370		77		6,476		19,375		262		19,742
Financing lease cost:
Amortization of right-of-use assets	657		693		1,372		1,793		1,944		3,802
Interest on lease liabilities	66		78		145		193		230		426
Amounts capitalized	(452)		(709)		(1,161)		(1,235)		(1,967)		(3,202)
Total financing lease expense	271		62		356		751		207		1,026
Variable lease expense	106		—		106		274		—		274
Short-term lease expense (1)	1,572		2		1,578		1,821		6		1,857
Total lease expense for the period	$	8,319	$	141	$	8,516	$	22,221	$	475	$	22,899

(1) Includes expense of $1.4 million for the three and nine months ended September 30, 2021 for rental of temporary cooling towers associated with the SJGS Unit 1 outage. These amounts are partially offset with insurance reimbursements of $0.9 million for the three and nine months ended September 30, 2021. For additional information on the SJGS Unit 1 outage see Note 12.

	Three Months Ended September 30, 2020						Nine Months Ended September 30, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating lease cost:	$	6,798	$	685	$	7,545	$	20,538	$	2,205	$	22,938
Amounts capitalized	(248)		(577)		(825)		(786)		(1,812)		(2,599)
Total operating lease expense	6,550		108		6,720		19,752		393		20,339
Financing lease cost:
Amortization of right-of-use assets	435		439		893		1,022		1,110		2,187
Interest on lease liabilities	58		74		134		156		198		358
Amounts capitalized	(281)		(452)		(733)		(682)		(1,105)		(1,787)
Total financing lease expense	212		61		294		496		203		758
Variable lease expense	63		—		63		158		—		158
Short-term lease expense	16		4		22		176		5		183
Total lease expense for the period	$	6,841	$	173	$	7,099	$	20,582	$	601	$	21,438

76

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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

	Nine Months Ended						Nine Months Ended
	September 30, 2021						September 30, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	25,511	$	262	$	25,897	$	25,804	$	483	$	26,708
Operating cash flows from financing leases	65		24		92		58		32		94
Finance cash flows from financing leases	621		234		920		378		215		646
Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	—	$	317	$	317	$	—	$	—	$	—
Financing leases	2,898		2,642		5,567		5,635		6,309		11,985

For the nine months ended September 30, 2021, capitalized costs excluded from the operating and financing cash paid for leases above are $0.6 million and $1.2 million at PNM, $1.6 million and $2.0 million at TNMP, and $2.3 million and $3.2 million at PNMR. For the nine months ended September 30, 2020, capitalized costs excluded from the operating and financing cash paid for leases above are $0.8 million and $0.7 million at PNM, $1.8 million and $1.1 million at TNMP, and $2.6 million and $1.8 million at PNMR. These capitalized costs are reflected as investing activities on the Company’s Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2021 and 2020.

Future expected lease payments are shown below:

	As of September 30, 2021
	PNM				TNMP				PNMR Consolidated
	Financing		Operating		Financing		Operating		Financing		Operating
	(In thousands)
Remainder of 2021	$	709	$	334	$	800	$	538	$	1,532	$	935
2022	2,767		26,266		3,125		1,990		5,980		28,467
2023	2,649		17,735		2,906		1,750		5,607		19,665
2024	1,972		7,908		2,438		877		4,421		8,833
2025	1,164		6,946		1,545		702		2,710		7,685
Later years	1,335		27,520		1,417		76		2,752		27,816
Total minimum lease payments	10,596		86,709		12,231		5,933		23,002		93,401
Less: Imputed interest	337		9,310		685		366		1,027		10,065
Lease liabilities as of September 30, 2021	$	10,259	$	77,399	$	11,546	$	5,567	$	21,975	$	83,336

The above table includes $11.3 million, $15.0 million, and $26.3 million for PNM, TNMP, and PNMR at September 30, 2021 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. The Company’s contractual commitments for leases that have not yet commenced are insignificant.

(14)   Income Taxes

In December 2017, comprehensive changes in United States 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

77

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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. In addition, in 2019, the IRS issued regulations interpreting Tax Act amendments to depreciation provisions of the IRC that allow the Company to claim a bonus depreciation deduction on certain construction projects placed in service subsequent to the third quarter of 2017. See additional discussion of the impacts of the Tax Act in Note 18 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K. On March 27, 2020, the Coronavirus Aid, Relief and Economic Security Act (the “CARES Act”) was enacted. Among other things, the CARES Act includes tax provisions that generally loosen restrictions on NOL utilization and business interest deductions, and accelerate refunds of previously generated alternative minimum tax credits. In addition, the CARES Act includes a temporary provision allowing businesses to defer payments to the government for some payroll taxes. In 2020, the Company applied for $5.2 million of accelerated refunds of previously generated alternative minimum tax ("AMT") credits and deferred $7.0 million of payments for certain payroll taxes. The Company received the $5.2 million refund of prior AMT credits in June 2021. The CARES Act provisions related to NOL utilization and business interest deductions are not applicable for the Company.

Beginning February 2018, PNM’s NM 2016 Rate Case reflects the reduction in the federal corporate income tax rate, including amortization of excess deferred federal and state income taxes. In accordance with the order in that case, 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, and the unprotected portion of excess deferred federal income taxes to customers over a period of approximately twenty-three years. 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. PNMR, PNM, and TNMP will amortize federal and state excess deferred income taxes of $24.5 million, $15.2 million, and $9.3 million in 2021. See additional discussion of PNM’s NM 2016 Rate Case and TNMP’s 2018 Rate Case in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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 income taxes. Certain unusual or infrequently occurring items, including excess tax benefits related to stock awards and taxes on Merger-related costs are excluded from the estimated annual effective tax rate calculation. At September 30, 2021, PNMR, PNM, and TNMP estimated their effective income tax rates for the year ended December 31, 2021 would be 13.08%, 15.43%, and 11.12%. The primary difference between the statutory income tax rates and the effective tax rates is the effect of the reduction in income tax expense resulting from the amortization of excess deferred federal income taxes. During the three and nine months ended September 30, 2021, income tax expense calculated by applying the expected annual effective income tax rate to earnings before income taxes was further reduced by excess tax benefits related to stock awards of less than $0.1 million and $0.8 million for PNMR, of which less than $0.1 million and $0.6 million was allocated to PNM and less than $0.1 million and $0.2 million was allocated to TNMP, and by tax benefits on Merger-related costs of $0.3 million and $1.8 million for PNMR, less than $0.1 million and $0.1 million for PNM, and less than $0.1 million and $0.1 million for TNMP.

(15)   Related Party Transactions

PNMR, PNM, TNMP, and NMRD are considered related parties, as is PNMR Services Company, a wholly-owned subsidiary of PNMR that provides corporate services to PNMR 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, PNMR provides construction and operations and maintenance services to NMRD, a 50% owned subsidiary of PNMR Development. PNM purchases renewable energy from certain NMRD-owned facilities at a fixed price per MWh of energy produced. PNM also provides interconnection services to PNMR Development and NMRD. See Note 16 for additional discussion of NMRD.

78

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

The table below summarizes the nature and amount of related party transactions of PNMR, PNM, TNMP, and NMRD:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands)
Services billings:
PNMR to PNM	$	23,617	$	24,204	$	75,992	$	70,848
PNMR to TNMP	9,187		9,645		29,687		28,075
PNM to TNMP	107		106		319		295
TNMP to PNMR	—		35		24		106
PNMR to NMRD	55		74		165		199
Renewable energy purchases:
PNM from NMRD	3,384		3,723		9,473		7,646
Interconnection billings:
PNM to NMRD	225		—		225		350
PNM to PNMR	—		—		—		—
NMRD to PNM	—		—		1,276		—
Interest billings:
PNMR to PNM	—		—		—		6
PNM to PNMR	36		60		108		218
PNMR to TNMP	—		—		—		2
Income tax sharing payments:
PNMR to PNM	—		—		—		—
TNMP to PNMR	—		—		—		—

(16)   Equity Method Investment

As discussed in Note 1 of the Company's 2020 Annual Reports on Form 10-K, PNMR Development and AEP OnSite Partners created NMRD in September 2017 to pursue the acquisition, development, and ownership of renewable energy generation projects, primarily in the state of New Mexico. As of September 30, 2021, NMRD’s renewable energy capacity in operation was 135.1 MW. PNMR Development and AEP OnSite Partners each have a 50% ownership interest in NMRD. The investment in NMRD is accounted for using the equity method of accounting because PNMR’s ownership interest results in significant influence, but not control, over NMRD and its operations.

In the nine months ended September 30, 2021 and 2020, PNMR Development made cash contributions of zero and $23.3 million to NMRD to be used primarily for its construction activities. In February 2021, NMRD paid PNMR Development a dividend of $3.0 million of which, $2.4 million represented PNMR Development's cumulative equity in earnings of NMRD as of March 31, 2021 and is presented as cash flows from operating activities on the Condensed Consolidated Statement of Cash Flows for the nine months ended September 30, 2021. The portion of the dividend in excess of PNMR Development's cumulative equity in earnings of NMRD amounting to $0.6 million is presented as cash flows from investing activities.

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

	Results of Operations
	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands)
Operating revenues	$	3,543	$	3,462	$	10,179	$	7,769
Operating expenses	2,422		2,100		7,360		5,152
Net earnings	$	1,121	$	1,362	$	2,819	$	2,617

79

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

	Financial Position
	September 30,		December 31,
	2021		2020
	(In thousands)
Current assets	$	9,164	$	8,046
Net property, plant, and equipment	168,053		172,585
Non-current assets	2,448		1,900
Total assets	179,665		182,531
Current liabilities	1,166		841
Non-current liabilities	370		380
Owners’ equity	$	178,129	$	181,310

(17)     Goodwill

The excess purchase price over the fair value of the assets acquired and the liabilities assumed by PNMR 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. PNMR’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 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.

PNMR 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 PNMR 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

80

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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

For its annual evaluations performed as of April 1, 2020, PNMR performed a qualitative analysis for the PNM reporting unit and a quantitative analysis for the TNMP reporting unit. In addition to the typical considerations discussed above, the qualitative analysis considered changes in PNM’s expectations of future financial performance since the April 1, 2018 quantitative analysis performed for PNM, as well as the previous qualitative analyses through April 1, 2019. The April 1, 2018 quantitative evaluations indicated the fair value of the PNM reporting unit, which has goodwill of $51.6 million, exceeded its carrying value by approximately 19%. Based on an evaluation of these and other factors, the Company determined it was not more likely than not that the April 1, 2020 carrying value of PNM exceeded its fair value. Using the methods and considerations discussed above, the 2020 quantitative analysis indicated the fair value of the TNMP reporting unit, which has goodwill of $226.7 million, exceeded its carrying value by approximately 38%. Based on an evaluation of these and other factors, the Company determined it was not more likely than not that the April 1, 2020 carrying value of TNMP exceeded its fair value.

For its annual evaluations performed as of April 1, 2021, PNMR 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, 2020 qualitative analysis for PNM and the quantitative analysis for TNMP. This analysis considered Company specific events such as the Merger, potential impacts of legal and regulatory matters discussed in Note 11 and Note 12, including potential outcomes in PNM’s Four Corners 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, 2021 carrying values of PNM and TNMP exceeded their fair value. Since the April 1, 2021 annual evaluation, there have been no events, including the Merger (Note 18), or indications that the fair values of the reporting units with recorded goodwill have decreased below their carrying values.

(18)     Merger

On October 20, 2020, PNMR, Avangrid, and Merger Sub, entered into the Merger Agreement pursuant to which Merger Sub will merge with and into PNMR, with PNMR surviving the Merger as a wholly-owned subsidiary of Avangrid.

Pursuant to the Merger Agreement, each issued and outstanding share of the common stock of PNMR (other than (i) the issued shares of PNMR common stock that are owned by Avangrid, Merger Sub, PNMR or any wholly-owned subsidiary of Avangrid or PNMR, which will be automatically cancelled at the time the Merger is consummated (the "Effective Time") and (ii) shares of PNMR common stock outstanding immediately prior to the Effective Time and held by a holder who has not voted in favor of, or consented in writing to, the Merger who is entitled to, and who has demanded, payment for fair value of such shares) will be converted into the right to receive $50.30 in cash.

The proposed Merger has been unanimously approved by the Boards of Directors of PNMR, Avangrid and Merger Sub and approved by PNMR shareholders at the Special Meeting of Shareholders held on February 12, 2021. On January 20, 2021, the FTC notified PNMR and Avangrid that early termination of the waiting period under the HSR Act in connection with the Merger was granted. CFIUS completed its review of the Merger on February 2, 2021, and has concluded that there are no unresolved national security concerns with respect to the Merger. On March 10, 2021, PNMR and Avangrid received FCC approval of the transfer of operating licenses related to the Merger. On April 20, 2021, FERC issued an order authorizing the Merger. On May 6, 2021, the PUCT issued an order authorizing the Merger, and on May 25, 2021, the NRC approved the Merger. Consummation of the Merger remains subject to the satisfaction or waiver of certain customary closing conditions, including, without limitation, the absence of any material adverse effect on PNMR, the receipt of required regulatory approval from the NMPRC, and the agreements relating to the divestiture of Four Corners being in full force and effect and all applicable regulatory filings associated therewith being made. The agreement related to the divestiture has been entered into and related filings have been made with the NMPRC. The Merger is currently expected to close in the fourth quarter of 2021.

On April 20, 2021, the Joint Applicants, the NMAG, WRA, the International Brotherhood of Electrical Workers Local 611, Dine, Nava Education Project, the San Juan Citizens Alliance and To Nizhoni Ani, entered into a stipulation and

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

agreement in the Joint Application for approval of Merger pending before the NMPRC. Subsequently, CCAE, Onward Energy, Walmart, Interwest Energy Alliance, M-S-R Power and the Incorporated County of Los Alamos have joined an amended stipulation. An evidentiary hearing was held from August 11 - 19, 2021. Post hearing briefs were filed on September 21, 2021 and response briefs were filed on September 28, 2021.

The Merger Agreement provides for certain customary termination rights including the right of either party to terminate the Merger Agreement if the Merger is not completed on or before January 20, 2022 (subject to a three-month extension by either party if all of the conditions to the closing, other than the conditions related to obtaining regulatory approvals, have been satisfied or waived). The Merger Agreement further provides that, upon termination of the Merger Agreement under certain specified circumstances (including if Avangrid terminates the Merger Agreement due to a change in recommendation of the Board or if PNMR terminates the Merger Agreement to accept a superior proposal (as defined in the Merger Agreement)), PNMR will be required to pay Avangrid a termination fee of $130.0 million. In addition, the Merger Agreement provides that (i) if the Merger Agreement is terminated by either party due to a failure of a regulatory closing condition and such failure is the result of Avangrid’s breach of its regulatory covenants or (ii) Avangrid fails to effect the closing when all closing conditions have been satisfied and it is otherwise obligated to do so under the Merger Agreement, then, in either such case, upon termination of the Merger Agreement, Avangrid will be required to pay PNMR a termination fee of $184.0 million as the sole and exclusive remedy. Upon the termination of the Merger Agreement under certain specified circumstances involving a breach of the Merger Agreement, either PNMR or Avangrid will be required to reimburse the other party’s reasonable and documented out-of-pocket fees and expenses up to $10.0 million (which amount will be credited toward, and offset against, the payment of any applicable termination fee).

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following Management’s Discussion and Analysis of Financial Condition and Results of Operations for PNMR is presented on a combined basis, including certain information applicable to PNM and TNMP. The MD&A for PNM and TNMP is presented as permitted by Form 10-Q General Instruction H(2). This report uses the term “Company” when discussing matters of common applicability to PNMR, PNM, and TNMP. A reference to a “Note” in this Item 2 refers to the accompanying Notes to Condensed Consolidated Financial Statements (Unaudited) included in Item 1, unless otherwise specified. Certain of the tables below may not appear visually accurate due to rounding.

MD&A FOR PNMR

EXECUTIVE SUMMARY

Overview and Strategy

PNMR is a holding company with two regulated utilities serving approximately 805,000 residential, commercial, and industrial customers and end-users of electricity in New Mexico and Texas. PNMR’s electric utilities are PNM and TNMP. PNMR strives to create a clean and bright energy future for customers, communities, and shareholders. PNMR’s strategy and decision-making are focused on safely providing reliable, affordable, and environmentally responsible power built on a foundation of Environmental, Social and Governance (ESG) principles.

Recent Developments

Merger

On October 20, 2020, PNMR, Avangrid and Merger Sub entered into the Merger Agreement pursuant to which Merger Sub will merge with and into PNMR, with PNMR surviving the Merger as a wholly-owned subsidiary of Avangrid.

Pursuant to the Merger Agreement, each issued and outstanding share of the common stock of PNMR (other than (i) the issued shares of PNMR common stock that are owned by Avangrid, Merger Sub, PNMR or any wholly-owned subsidiary of Avangrid or PNMR, which will be automatically cancelled at the Effective Time and (ii) shares of PNMR common stock outstanding immediately prior to the Effective Time and held by a holder who has not voted in favor of, or consented in writing to, the Merger who is entitled to, and who has demanded, payment for fair value of such shares) at the Effective Time will be converted into the right to receive $50.30 in cash.

The proposed Merger has been unanimously approved by the Boards of Directors of PNMR, Avangrid and Merger Sub and approved by PNMR shareholders at the Special Meeting of Shareholders held on February 12, 2021. On January 20, 2021, the FTC notified PNMR and Avangrid that early termination of the waiting period under the HSR Act in connection with the Merger was granted. CFIUS completed its review of the Merger on February 2, 2021, and has concluded that there are no unresolved national security concerns with respect to the Merger. On March 10, 2021, PNMR and Avangrid received FCC approval of the transfer of operating licenses related to the Merger. On April 20, 2021, FERC issued an order authorizing the Merger. On May 6, 2021 the PUCT issued an order authorizing the Merger and on May 25, 2021 the NRC approved the Merger. Consummation of the Merger remains subject to the satisfaction or waiver of certain customary closing conditions, including, without limitation, the absence of any material adverse effect on PNMR, the receipt of required regulatory approval from the NMPRC, and the agreements relating to the divestiture of Four Corners being in full force and effect and all applicable regulatory filings associated therewith being made. The agreement relating to the divestiture of Four Corners has been entered into and related filings have been made with the NMPRC. The Merger is currently expected to close in the fourth quarter of 2021.

On April 20, 2021, the Joint Applicants, the NMAG, WRA, the International Brotherhood of Electrical Workers Local 611, Dine, Nava Education Project, the San Juan Citizens Alliance and To Nizhoni Ani, entered into a stipulation and agreement in the Joint Application for approval of Merger pending before the NMPRC. Subsequently, CCAE, Onward Energy, Walmart, Interwest Energy Alliance, M-S-R Power and the Incorporated County of Los Alamos have joined an amended stipulation. An evidentiary hearing was held from August 11 - 19, 2021. Post hearing briefs were filed on September 21, 2021. Response briefs were filed on September 28, 2021.

EIM

On April 1, 2021, PNM joined and began participating in the EIM. The EIM is a real-time wholesale energy trading market operated by the California Independent System Operator (CAISO) that enables participating electric utilities to buy and sell energy. The EIM aggregates the variability of electricity generation and load for multiple balancing authority areas and utility jurisdictions. In addition, the EIM facilitates greater integration of renewable resources through the aggregation of

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flexible resources by capturing diversity benefits from the expanding geographic footprint and the expanded potential uses for those resources. PNM completed a cost-benefit analysis, which indicated participation in the EIM would provide substantial benefits to retail customers. In 2018, PNM filed an application with the NMPRC requesting, among other things, to recover initial capital investments and authorization to establish a regulatory asset to recover other expenses that would be incurred in order to join the EIM. The NMPRC approved the establishment of a regulatory asset but deferred certain rate making issues, including but not limited to issues related to implementation and ongoing EIM costs and savings, the prudence and reasonableness of costs to be included in the regulatory asset, and the period over which costs would be charged to customers until PNM’s next general rate case filing.

Texas Winter Storm

In mid-February 2021, Texas experienced a severe winter storm delivering the coldest temperatures in 100 years for many parts of the state. As a result, the ERCOT market was not able to deliver sufficient generation load to the grid resulting in significant, statewide outages as ERCOT directed transmission operators to curtail thousands of firm load megawatts. TNMP complied with ERCOT directives to curtail the delivery of electricity in its service territory and did not experience significant outages on its system outside of the ERCOT directed curtailments. TNMP has deferred bad debt expense from defaulting REPs to a regulatory asset totaling $0.8 million at September 30, 2021, and will seek recovery in a general rate case. At this time, the Company does not expect significant financial impacts related to this event. For additional information on the Texas winter storm see Note 11.

Financial and Business Objectives

PNMR is focused on achieving three key financial objectives:

•Earning authorized returns on regulated businesses

•Delivering at or above industry-average earnings and dividend growth

•Maintaining investment grade credit ratings

In conjunction with these objectives, PNM and TNMP are dedicated to:

•Maintaining strong employee safety, plant performance, and system reliability

•Delivering a superior customer experience

•Demonstrating environmental stewardship in business operations, including transitioning to an emissions-free generating portfolio by 2040

•Supporting the communities in their service territories

Earning Authorized Returns on Regulated Businesses

PNMR’s success in accomplishing its financial objectives is highly dependent on two key factors: fair and timely regulatory treatment for its utilities and the utilities’ strong operating performance. The Company has multiple strategies to achieve favorable regulatory treatment, all of which have as their foundation a focus on the basics: safety, operational excellence, and customer satisfaction, while engaging stakeholders to build productive relationships. Both PNM and TNMP seek cost recovery for their investments through general rate cases, periodic cost of service filings, and various rate riders.

Fair and timely rate treatment from regulators is crucial to PNM and TNMP in earning their allowed returns and critical for PNMR to achieve its financial objectives. PNMR believes that earning allowed returns is viewed positively by credit rating agencies and that improvements in the Company’s ratings could lower costs to utility customers.

Additional information about rate filings is provided in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

State Regulation

The rates PNM and TNMP charge customers are subject to traditional rate regulation by the NMPRC, FERC, and the PUCT.

New Mexico 2016 Rate Case – In January 2018, the NMPRC approved a settlement agreement that authorized PNM to implement an increase in base non-fuel rates of $10.3 million, which includes a reduction to reflect the impact of the decrease in the federal corporate income tax rate and updates to PNM’s cost of debt (aggregating $47.6 million annually). This order was on PNM's application for a general increase in retail electric rates filed in December 2016 (the "NM 2016 Rate Case").

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The key terms of the order include:

•A ROE of 9.575%

•A requirement to return to customers over a three-year period the benefit of the reduction in the New Mexico corporate income tax rate to the extent attributable to PNM’s retail operations (Note 14)

•A disallowance of PNM’s ability to collect an equity return on certain investments aggregating $148.1 million at Four Corners, but allowing recovery of a debt-only return

•An agreement to not implement non-fuel base rate changes, other than changes related to PNM’s rate riders, with an effective date prior to January 1, 2020

•A requirement to consider the prudency of PNM’s decision to continue its participation in Four Corners in PNM's next general rate case filing

PNM implemented 50% of the approved increase for service rendered beginning February 1, 2018, and implemented the rest of the increase for service rendered beginning January 1, 2019.

On December 29, 2020, Sierra Club filed a motion to re-open the NM 2016 Rate Case. The motion requests that the NMPRC re-open the NM 2016 Rate Case for the limited purpose of conducting a prudence review of certain Four Corners capital expenditures that the NMPRC deferred in its order approving the settlement agreement. Alternatively, Sierra Club requested that the deferred prudence review be conducted, and given weight as appropriate, in the Four Corners Abandonment Application. On February 10, 2021, the NMPRC rejected Sierra Club’s motion to re-open the NM 2016 Rate Case and stated that issues on whether the terms of the ETA provide an opportunity for consideration of prudence for Four Corners undepreciated investments included in a financing order or what effects the rates approved in the NM 2016 Rate Case may have on determining energy transition cost should be considered in the Four Corners Abandonment Application. For additional information on the Four Corners Abandonment Application see Note 12.

2020 Decoupling Petition – 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. If approved, customer bills would not be impacted until January 1, 2022. On October 2, 2020, PNM requested an order to vacate the public hearing and stay 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 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 March 17, 2021, the NMPRC issued an order granting PNM's petition for declaratory order which commences a proceeding to address petitions. Oral arguments were made on July 15, 2021. See Note 12. PNM cannot predict the outcome of this matter.

PVNGS Leased Interest Abandonment Application - On April 2, 2021, PNM filed the PVNGS Leased Interest Abandonment Application. In the application PNM requested NMPRC authorization to decertify and abandon its Leased Interest and to create regulatory assets for the associated remaining undepreciated investments with consideration of cost recovery of the undepreciated investments in a future rate case. PNM also sought NMPRC approval to sell and transfer the PNM-owned assets and nuclear fuel supply associated with the Leased Interest to SRP, which will be acquiring the Leased Interest from the lessors upon termination of the existing leases. In addition, PNM sought NMPRC approval for a 150 MW solar PPA combined with a 40 MW battery storage agreement, and a stand-alone 100 MW battery storage agreement to replace the Leased Interest. To ensure system reliability and load needs are met in 2023, when a majority of the leases expire, PNM also requested NMPRC approval for a 300 MW solar PPA combined with a 150 MW battery storage agreement. On August 25, 2021, the NMPRC issued an order confirming PNM requires no further NMPRC authority to abandon the PVNGS Leased Interest and to sell and transfer the PNM-owned assets and nuclear fuel supply associated with the Leased Interest to SRP. The order bifurcated the issue of approval of the two PPAs and three battery storage agreements into a separate docket so it may proceed expeditiously and deferred a ruling on the other issues. For additional information on PNM's Leased Interest and the associated abandonment application see Note 12 and Note 13.

Advanced Metering – Currently, TNMP has approximately 262,000 advanced meters across its service territory. Beginning in 2019, the majority of costs associated with TNMP’s AMS program are being recovered through base rates. On July 14, 2021, TNMP filed a request with the PUCT to consider and approve its final reconciliation of the costs spent on the deployment of AMS from April 1, 2018 through December 31, 2018 of $9.0 million, and approve appropriate carrying charges until full collection. On September 13, 2021 the PUCT Staff filed a recommendation for approval of TNMP's application for substantially all costs. On October 2, 2020, TNMP filed an application with the PUCT for authorization to implement necessary technological upgrades of approximately $46 million to its AMS program by November 2022. On January 14, 2021, the PUCT approved TNMP's application. TNMP will seek recovery of the investment associated with the upgrade in a future general rate proceeding or distribution cost recovery factor filing.

In February 2016, PNM filed an application with the NMPRC requesting approval of a project to replace its existing customer metering equipment with Advanced Metering Infrastructure (“AMI”), which was denied. As ordered by the NMPRC,

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PNM’s 2020 filing for energy efficiency programs to be offered in 2021, 2022, and 2023 included a proposal for an AMI pilot project, although PNM did not recommend the proposal due to the limited benefits that are cost-effective under a pilot structure. On September 17, 2020, the hearing examiner in the energy efficiency case issued a recommended decision recommending that PNM's proposed 2021 energy efficiency and load management program be approved, with the exception of the proposed AMI pilot program. On October 28, 2020, the NMPRC approved the recommended decision.

Rate Riders and Interim Rate Relief – The PUCT has approved mechanisms that allow TNMP to recover capital invested in transmission and distribution projects without having to file a general rate case. The NMPRC has approved PNM recovering fuel costs through the FPPAC, as well as rate riders for renewable energy and energy efficiency. These mechanisms allow for more timely recovery of investments.

On April 5, 2021, TNMP filed its 2021 DCOS that requested an increase in annual distribution revenues of $14.0 million. TNMP requested a procedural schedule that would result in rates being effective in September 2021. On July 1, 2021, TNMP reached a unanimous settlement agreement with parties that would authorize TNMP to collect an increase in annual distribution revenues of $13.5 million beginning in September 2021. On September 23, 2021 the PUCT approved substantially all costs in the unanimous settlement. See Note 12.

FERC Regulation

Rates PNM charges wholesale transmission customers are subject to traditional rate regulation by FERC. Rates charged to wholesale electric transmission customers are based on a formula rate mechanism pursuant to which rates for wholesale transmission service are calculated annually in accordance with an approved formula. The formula includes updating cost of service components, including investment in plant and operating expenses, based on information contained in PNM’s annual financial report filed with FERC, as well as including projected transmission capital projects to be placed into service in the following year. The projections included are subject to true-up. Certain items, including changes to return on equity and depreciation rates, require a separate filing to be made with FERC before being included in the formula rate.

In May 2019, PNM filed an application with FERC requesting approval to purchase a new 153-mile long 345-kV transmission line and related facilities (the “Western Spirit Line”). Under related agreements, PNM will provide transmission service to approximately 800 MW of new wind generation to be located in eastern New Mexico beginning in 2021 using an incremental rate. All necessary regulatory approvals for PNM to purchase and provide transmission service from the Western Spirit Line have been obtained.

On March 12, 2021, PNM filed four unexecuted TSAs with FERC totaling 145 MW with Leeward Energy. The unexecuted TSAs provide long-term firm, point-to-point transmission service on PNM’s transmission system. The unexecuted TSAs are based on the pro-forma transmission service agreements with certain non-conforming provisions under Attachment A of PNM’s OATT and include PNM’s OATT rate. PNM filed the unexecuted TSAs at the request of Leeward because the parties were unable to reach an agreement on the terms and conditions for transmission service. On May 11, 2021 FERC issued an order accepting PNM's four unexecuted TSAs based on PNM's proposed pricing scheme included in its OATT rate. On June 10, 2021, Pattern and Leeward both filed a request for rehearing of the FERC Order. On September 10, 2021, Leeward filed a petition in the United States District Court for the District of Columbia for review of FERC's order accepting PNM's four unexecuted TSAs. See Note 12.

Delivering At or Above Industry-Average Earnings and Dividend Growth

PNMR’s financial objective to deliver at or above industry-average earnings and dividend growth enables investors to realize the value of their investment in the Company’s business. Earnings growth is based on ongoing earnings, which is a non-GAAP financial measure that excludes from GAAP earnings certain non-recurring, infrequent, and other items that are not indicative of fundamental changes in the earnings capacity of the Company’s operations. PNMR uses ongoing earnings to evaluate the operations of the Company and to establish goals, including those used for certain aspects of incentive compensation, for management and employees.

PNMR targets a dividend payout ratio in the 50% to 60% range of its ongoing earnings. PNMR expects to provide at or above industry-average dividend growth in the near-term. The Board will continue to evaluate the dividend on an annual basis, considering sustainability and growth, capital planning, and industry standards.

Under the terms of the Merger Agreement, PNMR has agreed not to declare, set aside, make or pay any dividend or other distribution, payable in cash, stock, property or otherwise, with respect to any of its equity securities, or make any other actual, constructive or deemed distribution in respect of any equity securities (except (i) PNMR may continue the declaration and payment of planned regular quarterly cash dividends on PNMR common stock for each quarterly period ended after the date of the Merger Agreement, in an amount not to exceed $0.3275 for any fiscal quarters in 2021 and 2022, with usual record and payment dates in accordance with past dividend practice, and (ii) for any cash dividend or cash distribution by a wholly-owned subsidiary of PNMR to PNMR or another wholly-owned subsidiary of PNMR).

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The Board approved the following increases in the indicated annual common stock dividend:

Approval Date	Percent Increase
December 2019	6.0%
December 2020	6.5%

Maintaining Investment Grade Credit Ratings

The Company is committed to maintaining investment grade credit ratings in order to reduce the cost of debt financing and to help ensure access to credit markets, when required. See the subheading Liquidity included in the full discussion of Liquidity and Capital Resources below for the specific credit ratings for PNMR, PNM, and TNMP. All of the credit ratings issued by both Moody’s and S&P on the Company’s debt continue to be investment grade.

Business Focus

To achieve its business objectives, focus is directed in key areas: Safe, Reliable and Affordable Power; Utility Plant and Strategic Investments; Environmentally Responsible Power; and Customer, Stakeholders, and Community Engagement. The Company works closely with its stakeholders to ensure that resource plans and infrastructure investments benefit from robust public dialogue and balance the diverse needs of our communities. Equally important is the focus of PNMR’s utilities on customer satisfaction and community engagement.

Safe, Reliable, and Affordable Power

Safety is the first priority of our business and a core value of the Company. PNMR utilizes a Safety Management System to provide clear direction, objectives and targets for managing safety performance and minimizing risks and empowers employees to "Be the Reason Everyone Goes Home Safe".

PNMR measures reliability and benchmark performance of PNM and TNMP against other utilities using industry-standard metrics, including System Average Interruption Duration Index ("SAIDI") and System Average Interruption Frequency Index ("SAIFI"). PNM's and TNMP's investment plans include projects designed to support reliability and reduce the amount of time customers are without power.

PNMR and its utilities are aware of the important roles they play in enhancing economic vitality in their service territories. Management believes that maintaining strong and modern electric infrastructure is critical to ensuring reliability and supporting economic growth. When contemplating expanding or relocating their operations, businesses consider energy affordability and reliability to be important factors. PNM and TNMP strive to balance service affordability with infrastructure investment to maintain a high level of electric reliability and to deliver a safe and superior customer experience. Investing in PNM’s and TNMP’s infrastructure is critical to ensuring reliability and meeting future energy needs. Both utilities have long-established records of providing customers with safe and reliable electric service.

In March 2020, the World Health Organization declared COVID-19 a global pandemic and President Trump declared the COVID-19 pandemic a national emergency in the U.S. The Company continues to closely monitor developments and has taken and continues to take steps to mitigate the potential risks related to the COVID-19 pandemic. The Company has assessed and updated its existing business continuity plans in response to the impacts of the pandemic through crisis team meetings and working with other utilities and operators. It has identified its critical workforce, staged backups and limited access to control rooms and critical assets. The Company has worked to protect the safety of its employees using a number of measures, including minimizing exposure to other employees and the public and supporting flexible arrangements for all applicable job functions. The Company is also working with its suppliers to manage the impacts to its supply chain and remains focused on the integrity of its information systems and other technology systems used to run its business. However, the Company cannot predict the extent or duration of the ongoing COVID-19 pandemic, its effects on the global, national or local economy, or on the Company's financial position, results of operations, and cash flows. The Company will continue to monitor developments related to COVID-19 and will remain focused on protecting the health and safety of its customers, employees, contractors, and other stakeholders, and on its objective to provide safe, reliable, affordable and environmentally responsible power. As discussed in Note 12, both PNM and TNMP suspended disconnecting certain customers for past due bills, waived late fees during the pandemic, and have been provided regulatory mechanisms to recover these and other costs resulting from COVID-19.

Utility Plant and Strategic Investments

Utility Plant Investments – During the 2019 and 2020 periods, PNM and TNMP together invested $1.3 billion in utility plant, including substations, power plants, nuclear fuel, and transmission and distribution systems. New Mexico’s clean energy

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future depends on a reliable, resilient, secure grid to deliver an evolving mix of energy resources to customers. PNM has launched the Wired for the Future capital initiative, which emphasizes new investments in its transmission and distribution infrastructure with three primary objectives: delivering clean energy, enhancing customer satisfaction and increasing grid resilience. Projects are aimed at advancing the infrastructure beyond its original architecture to a more flexible and redundant system accommodating growing amounts of intermittent and distributed generation resources and integrating evolving technologies that provide long-term customer value. See the subheading Capital Requirements included in the full discussion of Liquidity and Capital Resources below for additional discussion of the Company’s projected capital requirements.

Strategic Investments – In 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. Abundant renewable resources, large tracts of affordable land, and strong government and community support make New Mexico a favorable location for renewable generation. New Mexico ranks third in the Nation for energy potential from solar power according to the Nebraska Department of Energy & Energy Sun Index and ranks third in the Nation for land-based wind capacity according to the U.S. Office of Energy Efficiency and Renewable Energy. PNMR Development and AEP OnSite Partners each have a 50% ownership interest in NMRD. Through NMRD, PNMR anticipates being able to provide additional renewable generation solutions to customers within and surrounding its regulated jurisdictions through partnering with a subsidiary of one of the United States’ largest electric utilities. As of September 30, 2021, NMRD’s renewable energy capacity in operation was 135.1 MW, which includes 130 MW of solar-PV facilities to supply energy to the Facebook data center located within PNM’s service territory, 1.9 MW to supply energy to Columbus Electric Cooperative located in southwest New Mexico, 2.0 MW to supply energy to the Central New Mexico Electric Cooperative, and 1.2 MW of solar-PV facilities to supply energy to the City of Rio Rancho, New Mexico. In addition, PNM's February 8, 2021 application with the NMPRC for approval to service the Facebook data center includes construction of a 50 MW solar facility owned by NMRD, which is expected to be operational in 2023. See Note 12. NMRD actively explores opportunities for additional renewable projects, including large-scale projects to serve future data centers and other customer needs.

Integrated Resource Plan

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 four years of that period.

NMPRC rules required PNM to file its 2020 IRP in July 2020. In April 2020, the NMPRC approved PNM's request to extend the deadline to file its 2020 IRP until six months after the NMPRC issues a final order approving replacement resources in PNM’s SJGS Abandonment Application. On January 29, 2021, PNM filed its 2020 IRP. The plan focuses on a carbon-free electricity portfolio by 2040 that would eliminate coal at the end of 2024. This includes replacing the power from San Juan with a mix of approved carbon-free resources and the plan to exit Four Corners at the end of 2024. The plan highlights the need for additional investments in a diverse set of resources, including renewables to supply carbon-free power, energy storage to balance supply and demand, and efficiency and other demand-side resources to mitigate load growth.

Environmentally Responsible Power

PNMR has a long-standing record of environmental stewardship. PNM’s environmental focus is in three key areas:

•Developing strategies to provide reliable and affordable power while transitioning to a 100% emissions-free generating portfolio by 2040

•Preparing PNM’s system to meet New Mexico’s increasing renewable energy requirements as cost-effectively as possible

•Increasing energy efficiency participation

PNMR’s corporate website (www.pnmresources.com) includes a dedicated section providing key environmental and other sustainability information related to PNM’s and TNMP’s operations and other information that collectively demonstrates the Company’s commitment to ESG principles. This information highlights plans for PNM to be coal-free by 2024 (subject to regulatory approval) and to achieve an emissions-free generating portfolio by 2040.

On September 21, 2020, PNM announced an agreement to partner with Sandia National Laboratories in research and development projects focused on energy resiliency, clean energy, and national security. The partnership demonstrates PNMR's commitment to ESG principles and its support of projects that further its emissions-free generation goals and plans for a reliable, resilient, and secure grid to deliver New Mexico's clean energy future.

The Energy Transition Act (“ETA”)

On June 14, 2019, Senate Bill 489, known as the ETA, became effective. The ETA amends the REA and requires utilities operating in New Mexico to have renewable portfolios equal to 20% by 2020, 40% by 2025, 50% by 2030, 80% by 2040, and 100% zero-carbon energy by 2045. The ETA also amends sections of the REA to allow for the recovery of

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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 provides for a transition from fossil-fueled generating resources to renewable and other carbon-free resources by allowing utilities to issue securitized bonds, or “energy transition bonds,” related to the retirement of certain coal-fired generating facilities to qualified investors. See additional discussion of the ETA in Note 11 and in Note 16 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

PNM expects the ETA will have a significant impact on PNM’s future generation portfolio, including PNM’s planned retirement of SJGS in 2022 and the planned Four Corners exit in 2024. PNM cannot predict the full impact of the ETA on potential future generating resource abandonment and replacement filings with the NMPRC.

SJGS Abandonment Application – As discussed in Note 12, on July 1, 2019, PNM filed a Consolidated Application for the Abandonment and Replacement of SJGS and Related Securitized Financing Pursuant to the ETA (the “SJGS Abandonment Application”). The SJGS Abandonment Application sought NMPRC approval to retire PNM’s share of SJGS in mid-2022, and for approval of replacement resources and the issuance of approximately $361 million of Securitized Bonds as provided by the ETA.

The NMPRC issued an order requiring the SJGS Abandonment Application be considered in two proceedings: one addressing SJGS abandonment and related financing and the other addressing replacement resources but did not definitively indicate if the abandonment and financing proceedings would be evaluated under the requirements of the ETA. After several requests for clarification and legal challenges, in January 2020, the NM Supreme Court ruled the NMPRC is required to apply the ETA to all aspects of PNM’s SJGS Abandonment Application, and that any previous NMPRC orders inconsistent with their ruling should be vacated.

In February 2020, the hearing examiners issued two recommended decisions recommending approval of PNM’s proposed abandonment of SJGS, subject to approval of the separate replacement resources proceeding, and approval of PNM’s proposed financing order to issue Securitized Bonds.  The hearing examiners recommended, among other things, that PNM be authorized to abandon SJGS by June 30, 2022, to issue Securitized Bonds of up to $361 million, and to establish the Energy Transition Charge. The hearing examiners recommended an interim rate rider adjustment upon the start date of the Energy Transition Charge to provide immediate credits to customers for the full value of PNM’s revenue requirement related to SJGS until those reductions are reflected in base rates. In addition, the hearing examiners recommended PNM be granted authority to establish regulatory assets to recover costs that PNM will pay prior to the issuance of the Securitized Bonds, including costs associated with the bond issuances as well as for severances, job training, and economic development funds. On April 1, 2020, the NMPRC unanimously approved the hearing examiners' recommended decisions regarding the abandonment of SJGS and the Securitized Bonds.

On June 24, 2020, the hearing examiners issued a second recommended decision on PNM's request for approval of replacement resources that addressed the entire portfolio of replacement resources. On July 29, 2020, the NMPRC issued an order approving resource selection criteria identified in the ETA that include PPA's for 650 MW of solar and 300 MW of battery storage. See additional discussion of the ETA and PNM’s San Juan Abandonment Application in Notes 11 and 12.

Four Corners Abandonment Application - On January 8, 2021, PNM filed the Four Corners Abandonment Application, which seeks NMPRC approval to exit PNM’s 13% share of Four Corners as of December 31, 2024, and issuance of approximately $300 million of energy transition bonds as provided by the ETA. As ordered by the hearing examiner in the case, PNM filed an amended application and testimony on March 15, 2021. The amended application provided additional information to support PNM's request, provided background on the NMPRC's consideration of the prudence of PNM's investment in Four Corners in the NM 2016 Rate Case and explained how the proposed sale and abandonment provides a net public benefit. If approved, PNM would exit its 200 MW ownership interest in Four Corners seven years earlier than planned and accelerate its exit of coal to 2024. See additional discussion of the ETA and PNM’s Four Corners Abandonment Application in Notes 11 and 12.

PNM enhanced its plan to exit Four Corners and emphasized its ESG strategy to reduce carbon emissions on March 12, 2021 with an announcement for additional plans for seasonal operations at Four Corners beginning in the fall of 2023. The solution for seasonal operations ensures the plant will be available to serve each owners' customer needs during times of peak energy use while minimizing operations during periods of low demand. This approach results in an estimated annual 20 to 25 percent reduction in carbon emissions at the plant and retains jobs and royalty payments for the Navajo Nation.

The Community Solar Act

On June 18, 2021, Senate Bill 84, known as the Community Solar Act, became effective. The Community Solar Act establishes a program that allows for the development of community solar facilities and provides customers of a qualifying utility with the option of accessing solar energy produced by a community solar facility in accordance with the Community Solar Act. The NMPRC is charged with administering the Community Solar Act program, establishing a total maximum

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capacity of 200 MW community solar (applicable until November 2024) facilities and allocating proportionally to the New Mexico electric investor-owned utilities and participating cooperatives. As required under the Community Solar Act, the NMPRC opened a docket on May 12, 2021, to adopt rules to establish a community solar program no later than April 1, 2022. See Note 12.

Other Environmental Matters – Four Corners may be required to comply with environmental rules that affect coal-fired generating units, including regional haze rules and the ETA.  On June 19, 2019, EPA repealed the Clean Power Plan, promulgated the ACE Rule, and revised the implementing regulations for all emission guidelines issued under the CAA Section 111(d). EPA set the Best System of Emissions Reduction (“BSER”) for existing coal-fired power plants as heat rate efficiency improvements based on a range of “candidate technologies” that can be applied inside the fence-line. Rather than setting a specific numerical standard of performance, EPA’s rule directs states to determine which of the candidate technologies to apply to each coal-fired unit and establish standards of performance based on the degree of emission reduction achievable based on the application of BSER. However, on January 19, 2021, the DC Circuit issued an opinion vacating and remanding the rule, holding that it was based on a misconstruction of Section 111(d) of the Clean Air Act. In addition, on January 27, 2021, President Biden signed an executive order requiring a review of environmental regulations issued under the Trump Administration, which will include a review of the ACE rule. The Biden Administration has made clear that it will seek greater authority in regulating greenhouse gas emissions to address climate change.

PNMR is building upon its ESG goal of 100% emissions-free generation by 2040 with plans for additional emissions reductions through the electrification of its vehicle fleet. Growing the number of electric vehicles within the Company's fleet will benefit the environment and lower fuel costs furthering the commitment to ESG principles. Under the commitment, existing fleet vehicles will be replaced as they are retired with an increasing percentage of electric vehicles. The new goals call for 25% of all light duty fleet purchases to be electric by 2025 and 50% to be electric by 2030.

To demonstrate PNMR’s commitment to increase the electrification of vehicles in its service territory, PNM filed a Transportation Electrification Program (“TEP”) with the NMPRC on December 18, 2020. The TEP supports customer adoption of electric vehicles by focusing on addressing the barriers to electric vehicle adoption and encourage use. PNM’s proposed program budget will be dedicated to low and moderate income customers by providing rebates to both residential and non-residential customers towards the purchase of chargers and/or behind-the-meter infrastructure. See Note 12.

Renewable Energy

PNM’s renewable procurement strategy includes utility-owned solar capacity, as well as solar, wind and geothermal energy purchased under PPAs. As of September 30, 2021, PNM has 158 MW of utility-owned solar capacity in operation. In addition, PNM purchases power from a customer-owned distributed solar generation program that had an installed capacity of 190.8 MW at September 30, 2021. PNM also owns the 500 KW PNM Prosperity Energy Storage Project. The project was one of the first combinations of battery storage and solar-PV energy in the nation and involved extensive research and development of advanced grid concepts. The facility also was the nation’s first solar storage facility fully integrated into a utility’s power grid. PNM also purchases the output from New Mexico Wind, a 200 MW wind facility, and the output of Red Mesa Wind, an existing 102 MW wind energy center. PNM's 2020 renewable energy procurement plan was approved by the NMPRC in January 2020 and includes a PPA to procure 140 MW of renewable energy and RECs from La Joya Wind II that began in June 2021. The NMPRC's approved portfolio to replace the planned retirement of SJGS will result in PNM executing solar PPAs of 650 MW combined with 300 MW of battery storage facilities. The majority of these renewable resources are key means for PNM to meet the RPS and related regulations that require PNM to achieve prescribed levels of energy sales from renewable sources, including those set by the recently enacted ETA, without exceeding cost requirements.

As discussed in Strategic Investments above, PNM is currently purchasing the output of 130 MW of solar capacity from NMRD that is used to serve the Facebook data center which includes two 25-year PPAs to purchase renewable energy and RECs from an aggregate of approximately 100 MW of capacity from two solar-PV facilities constructed by NMRD to supply power to Facebook, Inc. The first 50 MW of these facilities began commercial operations in November 2019 and the second 50 MW facility began commercial operations in July 2020. Additionally, PNM has entered into three separate 25-year PPAs to purchase renewable energy and RECs to be used by PNM to supply additional renewable power to the Facebook data center. These PPAs include the purchase of power and RECs from a 50 MW wind project, which was placed in commercial operation in November 2018, a 166 MW wind project which became operational in February 2021, and a 50 MW solar-PV project to be operational in the first quarter of 2022. On February 8, 2021, PNM filed an application with the NMPRC for approval to service the Facebook data center for an additional 190 MW of solar PPA combined with 100 MW of battery storage and a 50 MW solar PPA expected to be operational in 2023. See Note 12.

In March 2020, the NMPRC approved the PNM Solar Direct program under which qualified governmental and large commercial customers could participate in a voluntary renewable energy procurement program. The costs of the program would be recovered directly from subscribing customers through a rate rider, including the costs to procure renewable energy from 50 MW of solar-PV facilities under a 15-year PPA. These facilities are expected to be placed in commercial operation in the first quarter of 2022.

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PNM will continue to procure renewable resources while balancing the impact to customers’ electricity costs in order to meet New Mexico’s escalating RPS and carbon-free resource requirements.

Energy Efficiency

Energy efficiency plays a significant role in helping to keep customers’ electricity costs low while meeting their energy needs and is one of the Company’s approaches to supporting environmentally responsible power. PNM’s and TNMP’s energy efficiency and load management portfolios continue to achieve robust results. In 2020, incremental energy saved as a result of new participation in PNM’s portfolio of energy efficiency programs exceeded 87 GWh, which was the maximum level of profit incentive allowed under the NMPRC approved program. This is equivalent to the annual consumption of approximately 12,155 homes in PNM’s service territory. PNM’s load management and annual energy efficiency programs also help lower peak demand requirements. In 2020, TNMP’s incremental energy saved as a result of new participation in TNMP’s energy efficiency programs is estimated to be approximately 17 GWh. This is equivalent to the annual consumption of approximately 2,011 homes in TNMP’s service territory. TNMP’s High-Performance Homes residential new construction energy efficiency program was honored for the 6th year in a row by ENERGY STAR. This recognition includes the program’s 4th straight Partner of the Year Sustained Excellence Award. For information on PNM's and TNMP's energy efficiency filing with the NMPRC and PUCT see Note 12.

Water Conservation and Solid Waste Reduction

PNM continues its efforts to reduce the amount of fresh water used to make electricity (about 35% more efficient than in 2007). Continued growth in PNM’s fleet of solar and wind energy sources, energy efficiency programs, and innovative uses of gray water and air-cooling technology have contributed to this reduction. Water usage has continued to decline as PNM has substituted less fresh-water-intensive generation resources to replace SJGS Units 2 and 3 starting in 2018, as water consumption at that plant has been reduced by approximately 50%. As the Company moves forward with its mission to achieve 100% carbon-free generation by 2040, it expects that more significant water savings will be gained. PNM has set a goal to reduce freshwater use 80% by 2035 and 90% by 2040 from 2005 levels. Focusing on responsible stewardship of New Mexico’s scarce water resources improves PNM’s water-resilience in the face of persistent drought and ever-increasing demands for water to spur the growth of New Mexico’s economy.

In addition to the above areas of focus, the Company is working to reduce the amount of solid waste going to landfills through increased recycling and reduction of waste. In 2020, 18 of the Company’s 23 facilities met the solid waste diversion goal of a 65% diversion rate. The Company expects to continue to do well in this area in the future.

Customer, Stakeholder, and Community Engagement

Another key element of the Company’s commitment to ESG principles is fostering relationships with its customers, stakeholders and communities. The Company strives to deliver a superior customer experience. Through outreach, collaboration, and various community-oriented programs, the Company has demonstrated a commitment to building productive relationships with stakeholders, including customers, community partners, regulators, intervenors, legislators, and shareholders. PNM continues to focus its efforts to enhance the customer experience through customer service improvements, including enhanced customer service engagement options, strategic customer outreach, and improved communications. These efforts are supported by market research to understand the varying needs of customers, identifying and establishing valued services and programs, and proactively communicating and engaging with customers. As a result, PNM has seen significant gains in customer satisfaction in recent years in both the JD Power Electric Utility Residential Customer Satisfaction StudySM and its own proprietary relationship surveys. In September 2020, J.D, Power also ranked PNM as one of the top performers in the industry for improved impression of the Company based on PNM's response to the COVID-19 pandemic.

The Company has leveraged a number of communications channels and strategic content to better serve and engage its many stakeholders. PNM’s website www.pnm.com, provides the details of major regulatory filings, including general rate requests, as well as the background on PNM’s efforts to maintain reliability, keep prices affordable, and protect the environment. The Company’s website is also a resource for information about PNM’s operations and community outreach efforts, including plans for building a sustainable energy future for New Mexico and to transition to an emissions-free generating portfolio by 2040. PNM has also leveraged social media in communications with customers on various topics such as education, outage alerts, safety, customer service, and PNM’s community partnerships in philanthropic projects. As discussed above, PNMR's corporate website, www.pnmresources.com, includes a dedicated section providing additional information regarding the Company’s commitment to ESG principles and other sustainability efforts.

With reliability being the primary role of a transmission and distribution service provider in Texas’ deregulated market, TNMP continues to focus on keeping end-users updated about interruptions and to encourage consumer preparation when severe weather is forecasted. This quarter, TNMP provided a 30-person team in support of another utility that experienced significant damage to their transmission and distribution system as a result of Hurricane Ida. TNMP has been honored by the

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Edison Electric Institute four times since 2012 for its assistance to out-of-state utilities affected by hurricanes. TNMP has also been honored twice for hurricane response in its own territory.

Local relationships and one-on-one communications remain two of the most valuable ways both PNM and TNMP connect with their stakeholders. Both companies maintain long-standing relationships with governmental representatives and key electricity consumers to ensure that these stakeholders are updated on Company investments and initiatives. Key electricity consumers also have dedicated Company contacts that support their important service needs.

Another demonstration of the Company's commitment to ESG principles is the Company’s tradition of supporting the communities it serves in New Mexico and Texas. This support extends beyond corporate giving and financial donations from the PNM Resources Foundation to also include collaborations on community projects, customer low-income assistance programs, and employee volunteerism. In response to COVID-19, additional efforts were made in each of these areas and exhibit the Company’s core value of caring for its customers and communities.

During the three years ending December 31, 2020, corporate giving contributed $7.7 million to civic, educational, environmental, low income, and economic development organizations. PNMR recognizes its responsibility to support programs and organizations that enrich the quality of life across its service territories and seeks opportunities to further demonstrate its commitment in these areas as needs arise. In response to COVID-19 community needs, PNMR donated to an Emergency Action Fund in partnership with key local agencies to benefit approximately ninety nonprofits and small businesses facing challenges due to lack of technology, shifting service needs, and cancelled fundraising events. Additionally, employee teams have supported first responders and other front-line workers through the delivery of food and other supplies often procured from local businesses struggling during stay-at-home orders. PNM also donated to the Pueblo Relief Fund and delivered personal protective supplies to pueblo areas and tribal nations throughout New Mexico. While its service territory does not include the Navajo Nation, PNM’s operations include generating facilities and employees in this region that has been disproportionately affected by the pandemic. In response, employee teams focused efforts to this region and also provided available supplies of personal protective equipment. PNM has also collaborated with the Navajo Tribal Utility Authority Wireless ("NTUAW") to set up wireless “hot spots” throughout the Navajo Nation in areas without internet access to assist first responders and support continued education opportunities amidst school closures. These actions supplement PNM’s continued support for the Navajo Nation. The PNM Navajo Nation Workforce Training Scholarship Program provides support for Navajo tribal members and encourages the pursuit of education and training in existing and emerging jobs in the communities in which they live. In 2019, PNM invested an additional $500,000 into this scholarship program to further assist in the development and education of the Navajo Nation workforce. PNM has invested in paid summer college engineering internship programs for American Indian students available in the greater Albuquerque area. PNM also continues to partner in the Light up Navajo project, piloted in 2019 and modeled after mutual aid to connect homes without electricity to the power grid. In 2020, PNM also partnered with key local organizations to initiate funding for programs focused on diversity, equity, and inclusion.

Another important outreach program is tailored for low-income customers and includes the PNM Good Neighbor Fund to provide customer assistance with their electric utility bills. COVID-19 has increased the needs of these customers along with customers who may not otherwise need to seek assistance. In addition to the suspension of customer disconnections and expansion of customer payment plans, PNM responded with increased communications through media outlets and customer outreach to connect customers with nonprofit community service providers offering financial assistance, food, clothing, medical programs, and services for seniors. As a result of these communication efforts, 3,487 families in need received emergency assistance through the PNM Good Neighbor Fund during 2020.

Additionally, as a part of corporate giving, on October 1, 2020, PNM introduced $2.0 million in funding for new COVID Customer Relief Programs to support income-qualified residential customers and small business customers who have been impacted by the financial challenges created by COVID-19 and have past due electric bills. Qualified customers that pay a portion of their past-due balance can receive assistance toward their remaining balance.

Volunteerism is also an important facet of employee culture, keeping our communities safer, stronger, smarter and more vibrant. In 2020, PNM and TNMP employees and retirees contributed over 6,200 virtual and in-person volunteer hours serving local communities by supporting at least 250 organizations. Volunteers also participate in a company-wide annual Day of Service at nonprofits across New Mexico and Texas along with participation on a variety of nonprofit boards and independent volunteer activities throughout the year.

In addition to the extensive engagement both PNM and TNMP have with nonprofit organizations in their communities, the PNM Resources Foundation provides more than $1 million in grant funding each year across New Mexico and Texas. These grants help nonprofits innovate or sustain programs to grow and develop business, develop and implement environmental programs, and provide educational opportunities. Beginning in 2020, the PNM Resources Foundation is funding grants with a three-year focus on decreasing homelessness, increasing access to affordable housing, reducing carbon emissions, and community safety with an emphasis on COVID-19 programs. As part of this emphasis, $0.5 million has been awarded to nonprofits in New Mexico to assist with work being done on the front lines of the pandemic for community safety, with a focus on helping senior citizens and people currently experiencing homelessness during the shelter-in-place directives. In 2020, the

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PNM Resources Foundation expanded its matching donation program to offer 2-to-1 matching on employee donations made to social justice nonprofits and increased the annual amount of matching donations available to each of its employees. PNM Resources Foundation awarded $0.3 million of additional grants to non-profits supporting TNMP communities following the winter storm in February 2021.

Economic Factors

PNM – In the three and nine months ended September 30, 2021, PNM experienced increases of 2.2% and 0.8% in weather normalized retail load compared to 2020, reflecting signs of recovery from New Mexico state restrictions related to COVID-19.

TNMP – In the three and nine months ended September 30, 2021, TNMP experienced a decrease in volumetric weather normalized retail load of 2.2% and 1.0% compared to 2020. Weather normalized demand-based load, excluding retail transmission customers increased 2.8% and 2.4% in the three and nine months ended September 30, 2021 compared to 2020. TNMP has experienced increased demand-based load offset by decreases in its volumetric weather normalized retail load as Texas recovers from state restriction related to COVID-19.

Although the Company has begun to experience signs of recovery from state restrictions related to COVID-19, it is unable to determine the duration or final impacts from COVID-19 as discussed in more detail in Item 1A Risk Factors of the 2020 Annual Report on Form 10-K. The Company has not experienced, nor does it expect significant negative impacts to customer usage at PNM and TNMP resulting from the economic impacts of COVID-19. However, if current economic conditions worsen, the Company may be required to implement additional measures such as reducing or delaying operating and maintenance expenses and planned capital expenditures.

Results of Operations

Net earnings attributable to PNMR were $184.6 million, or $2.14 per diluted share in the nine months ended September 30, 2021 compared to $164.0 million, or $2.05 per diluted share, in 2020. Among other things, earnings in the nine months ended September 30, 2021, benefited from higher weather normalized retail load at PNM, higher demand-based load at TNMP, higher transmission rates at PNM and TNMP, higher distribution rates at TNMP, lower surface mine reclamation expense and lower accretion expense at PNM, lower interest expense at PNM, improved performance on PNM's NDT investment securities and higher equity AFUDC at PNM. These increases were partially offset by milder summer weather at PNM, higher operational and maintenance expense, including higher plant maintenance and administrative costs at PNM, higher employee related, outside service and vegetation management expense at PNM and TNMP, increased depreciation and higher property taxes at PNM and TNMP due to increased plant in service, and higher interest charges at TNMP. Additional information on factors impacting results of operations for each segment is discussed below under Results of Operations.

Liquidity and Capital Resources

PNMR and PNM have revolving credit facilities with capacities of $300.0 million and $400.0 million that currently expire in October 2023. Both facilities provide for short-term borrowings and letters of credit and can be extended through October 2024, subject to approval by a majority of the lenders. In addition, PNM has a $40.0 million revolving credit facility with banks having a significant presence in New Mexico that expires in December 2022, and TNMP has a $75.0 million revolving credit facility, which expires in September 2022 and contains two one-year extension options, subject to approval by a majority of the lenders. Total availability for PNMR on a consolidated basis was $798.8 million at October 22, 2021. The Company utilizes these credit facilities and cash flows from operations to provide funds for both construction and operational expenditures. PNMR also has intercompany loan agreements with each of its subsidiaries.

PNMR projects that its consolidated capital requirements, consisting of construction expenditures and dividends, will total $4.6 billion for 2021 - 2025, including amounts expended through September 30, 2021. The construction expenditures include estimated amounts for an anticipated expansion of PNM’s transmission system, including the planned purchase of the Western Spirit Line, and expenditures for PNM’s Wired for the Future capital initiative.

To fund capital spending requirements to meet growth that balances earnings goals, credit metrics and liquidity needs, the Company has entered into new financing arrangements in 2021. A complete listing of current financing arrangements is contained in Note 9 and Note 7 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

See discussion of the NMPRC's April 1, 2020 approval of PNM's request to issue approximately $361 million of Securitized Bonds upon the retirement of SJGS in 2022, and the related appeal of that order to the NM Supreme Court in Note 12.

After considering the effects of these financings and the Company's short-term liquidity position as of October 22, 2021, the Company has consolidated maturities of long-term and short-term debt aggregating approximately $115.1 million

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through October 2022. In addition to internal cash generation, the Company anticipates that it will be necessary to obtain additional long-term financing in the form of debt refinancing, new debt issuances, and/or new equity in order to fund its capital requirements during the 2021-2025 period. The Company currently believes that its internal cash generation, existing credit arrangements, and access to public and private capital markets will provide sufficient resources to meet the Company’s capital requirements for at least the next twelve months. The Company is in compliance with its debt covenants.

RESULTS OF OPERATIONS

The following discussion and analysis should be read in conjunction with the Condensed Consolidated Financial Statements and Notes thereto. Trends and contingencies of a material nature are discussed to the extent known. Refer also to Disclosure Regarding Forward Looking Statements and to Part II, Item 1A. Risk Factors.

A summary of net earnings attributable to PNMR is as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2021		2020		Change		2021		2020		Change
	(In millions, except per share amounts)
Net earnings attributable to PNMR	$	113.3	$	121.8	$	(8.5)	$	184.6	$	164.0	$	20.6
Average diluted common and common equivalent shares	86.1		79.9		6.2		86.1		80.0		6.1
Net earnings attributable to PNMR per diluted share	$	1.32	$	1.52	$	(0.20)	$	2.14	$	2.05	$	0.09

The components of the change in net earnings attributable to PNMR are:

	Three Months Ended		Nine Months Ended
	September 30, 2021		September 30, 2021
	(In millions)
PNM	$	(12.4)	$	18.0
TNMP	4.0		5.1
Corporate and Other	—		(2.5)
Net change	$	(8.5)	$	20.6

Information regarding the factors impacting PNMR’s operating results by segment are set forth below.

Segment Information

The following discussion is based on the segment methodology that PNMR’s management uses for making operating decisions and assessing performance of its various business activities. See Note 2 for more information on PNMR’s operating segments.

PNM

PNM defines utility margin as electric operating revenues less cost of energy, which consists primarily of fuel and purchase power costs. PNM believes that utility margin provides a more meaningful basis for evaluating operations than electric operating revenues since substantially all fuel and purchase power costs are offset in revenues as those costs are passed through to customers under PNM’s FPPAC. Utility margin is not a financial measure required to be presented and is considered a non-GAAP measure.

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The following table summarizes the operating results for PNM:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2021		2020		Change		2021		2020		Change
	(In millions)
Electric operating revenues	$	435.5	$	364.5	$	71.0	$	1,030.7	$	873.4	$	157.3
Cost of energy	170.9		108.3		62.6		383.6		250.7		132.9
Utility margin	264.6		256.2		8.4		647.1		622.7		24.4
Operating expenses	107.4		99.2		8.2		320.6		299.3		21.3
Depreciation and amortization	42.7		40.5		2.2		127.1		123.7		3.4
Operating income	114.6		116.5		(1.9)		199.4		199.7		(0.3)
Other income	4.7		14.8		(10.1)		24.1		8.4		15.7
Interest charges	(12.5)		(14.7)		2.2		(38.4)		(51.6)		13.2
Segment earnings before income taxes	106.8		116.6		(9.8)		185.0		156.5		28.5
Income (taxes)	(15.5)		(13.6)		(1.9)		(26.2)		(16.1)		(10.1)
Valencia non-controlling interest	(4.2)		(3.6)		(0.6)		(11.6)		(11.2)		(0.4)
Preferred stock dividend requirements	(0.1)		(0.1)		—		(0.4)		(0.4)		—
Segment earnings	$	86.9	$	99.3	$	(12.4)	$	146.8	$	128.8	$	18.0

The following table shows total GWh sales, including the impacts of weather, by customer class and average number of customers:

	Three Months Ended September 30,				Nine Months Ended September 30,
			Percentage				Percentage
	2021	2020	Change		2021	2020	Change
	(Gigawatt hours, except customers)
Residential	994.9	1,050.8	(5.3)	%	2,577.1	2,628.1	(1.9)	%
Commercial	1,048.1	987.8	6.1		2,701.8	2,640.0	2.3
Industrial	413.5	370.4	11.6		1,189.5	1,042.0	14.2
Public authority	67.9	74.5	(8.9)		172.6	182.7	(5.5)
Economy energy service (1)	123.4	93.1	32.5		365.5	354.4	3.1
Other sales for resale	1,592.5	734.5	116.8		3,958.4	1,994.7	98.4
	4,240.3	3,311.1	28.1	%	10,964.9	8,841.9	24.0	%
Average retail customers (thousands)	540.6	535.8	0.9	%	539.8	534.4	1.0	%

(1) PNM purchases energy for a large customer on the customer’s behalf and delivers the energy to the customer’s location through PNM’s transmission system. PNM charges the customer for the cost of the energy as a direct pass through to the customer with only a minor impact in utility margin resulting from providing ancillary services.

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Operating Results – Three Months Ended September 30, 2021 compared to 2020

The following table summarizes the significant changes to utility margin:

		Three Months Ended September 30, 2021
		Change
Utility margin:		(In millions)
	Retail customer usage/load – Weather normalized KWh sales increased 8.9% for commercial customers partially offset by decreased sales to residential customers of 1.6%	$	4.8
	Weather – Milder weather in 2021; cooling degree days were 11.7% lower in 2021	(6.9)
	Transmission – Higher revenues under formula transmission rates, the addition of a new customer, and higher volumes	7.7
	Rate riders – Includes renewable energy, fuel clause, and energy efficiency riders which are mostly offset in operating expense	1.6
	Coal mine reclamation – Lower expense on surface mine reclamation in 2021 and the 2020 remeasurement of PNM’s obligation for Four Corners and SJGS coal mine reclamation (Note 11)	1.4
	Other	(0.2)
	Net Change	$	8.4

The following tables summarize the primary drivers for changes in operating expenses, depreciation and amortization, other income (deductions), interest charges, and income taxes:

		Three Months Ended September 30, 2021
		Change
Operating expenses:		(In millions)
	Higher plant maintenance and administrative costs at SJGS, Four Corners, and gas-fired plants, partially offset by lower costs at PVNGS	$	1.8
	Higher property taxes due to increases in utility plant in service and timing of property value settlements in 2020	1.0
	Higher employee related, outside services, and vegetation management expenses	2.1
	Higher energy efficiency and renewable rider expenses, offset in utility margin	1.5
	2021 non-retail credit loss reserve	0.8
	2021 regulatory disallowance resulting from the PVNGS Leased Interest Abandonment Application (Note 12)	1.3
	Regulatory disallowance due to change in estimated write-offs associated with the SJGS BART determination and ownership restructuring	(0.8)
	Other	0.5
	Net Change	$	8.2

Depreciation and amortization:
	Increased utility plant in service	$	1.9
	Other	0.3
	Net Change	$	2.2

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		Three Months Ended September 30, 2021
		Change
Other income (deductions):		(In millions)
	Decreased performance on investment securities in the NDT and coal mine reclamation trusts	$	(12.5)
	Higher equity AFUDC	0.5
	Lower trust expenses and higher interest income related to investment securities in the NDT and coal mine reclamation trusts	0.3
	Decrease in donations including the 2020 COVID Customer Relief Program	1.8
	Other	(0.2)
	Net Change	$	(10.1)

Interest charges:
	Lower interest on term loans	$	0.9
	Lower debt AFUDC	(0.4)
	Refinancing of $160 million SUNs in July 2021	0.8
	Lower interest on PCRBs remarketed in 2020	0.8
	Other	0.1
	Net Change	$	2.2

Income (taxes) benefits:
	Lower segment earnings before income taxes	$	2.7
	Changes in the anticipated effective tax rate, including amortization of excess deferred income taxes (Note 14)	(5.8)
	Other	1.2
	Net Change	$	(1.9)

Operating Results – Nine Months Ended September 30, 2021 compared to 2020

The following table summarizes the significant changes to utility margin:

		Nine Months Ended September 30, 2021
		Change
Utility margin:		(In millions)
	Retail customer usage/load – Weather normalized KWh sales increased 3.8% for commercial customers and decreased 0.5% for residential customers	$	6.4
	Weather – Milder weather in the second and third quarters was partially offset by colder weather in the first quarter	(5.9)
	Leap Year – Decrease in revenue due to additional day in 2020	(1.8)
	Transmission – Higher revenues under formula transmission rates, the addition of a new customer, and higher volumes	13.9
	Rate riders – Includes renewable energy, fuel clause, and energy efficiency riders which are partially offset in operating expense	6.5
	Coal mine decommissioning - Lower expense on surface mine reclamation in 2021 and 2020 remeasurement of PNM's obligation for Four Corners and SJGS coal mine reclamation (Note 11)	5.1
	Other	0.2
	Net Change	$	24.4

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The following tables summarize the primary drivers for changes in operating expenses, depreciation and amortization, other income (deductions), interest charges, and income taxes:

		Nine Months Ended September 30, 2021
		Change
Operating expenses:		(In millions)
	Higher plant maintenance and administrative costs at SJGS, Four Corners, and gas-fired plants, partially offset by lower costs at PVNGS	$	5.9
	Higher property taxes due to increases in utility plant in service, partially offset by favorable settlement of property values	0.4
	Higher employee related, outside services, and vegetation management expenses	8.8
	Higher energy efficiency and renewable rider expenses offset in utility margin	4.0
	2021 non-retail credit loss reserve	0.8
	2021 Regulatory disallowance resulting from the PVNGS Leased Interest Abandonment Application (Note 12)	1.3
	Regulatory disallowance due to change in estimated write-offs associated with the SJGS BART determination and ownership restructuring	(0.8)
	Other	0.9
	Net Change	$	21.3

Depreciation and amortization:
	Increased utility plant in service	$	5.3
	Lower accretion expense for PVNGS plant decommissioning ARO resulting from 2020 study			(2.2)
	Other			0.3
	Net Change			$	3.4

Other income (deductions):
	Increased performance on investment securities in the NDT partially offset by decreased performance in the coal mine reclamation trusts	$	12.9
	Higher equity AFUDC	2.4
	Higher trust expenses partially offset by higher interest income related to investment securities in the NDT and coal mine reclamation trusts	(0.9)
	Decrease in donations including the 2020 COVID Customer Relief Program	1.4
	Other	(0.1)
	Net Change	$	15.7

Interest charges:
	Lower interest on term loans	$	3.7
	Refinancing of $160 million of SUNs in July 2021	0.8
	Issuance of $200.0 million of SUNs in April 2020	(2.3)
	Higher debt AFUDC resulting from FERC audit in 2020	1.9
	Lower interest on PCRBs remarketed in 2020	9.0
	Other	0.1
	Net Change	$	13.2

Income (taxes) benefits:
	Higher segment earnings before income taxes	$	(7.1)
	Changes in the anticipated effective tax rate, including amortization of excess deferred income taxes (Note 14)	(5.3)
	Other	2.3
	Net Change	$	(10.1)

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TNMP

TNMP defines utility margin as electric operating revenues less cost of energy, which consists of costs charged by third-party transmission providers. TNMP believes that utility margin provides a more meaningful basis for evaluating operations than electric operating revenues since all third-party transmission costs are passed on to consumers through a transmission cost recovery factor. Utility margin is not a financial measure required to be presented and is considered a non-GAAP measure.

The following table summarizes the operating results for TNMP:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2021		2020		Change		2021		2020		Change
	(In millions)
Electric operating revenues	$	119.0	$	108.0	$	11.0	$	315.1	$	290.3	$	24.8
Cost of energy	28.5		25.7		2.8		83.9		75.9		8.0
Utility margin	90.6		82.3		8.3		231.2		214.4		16.8
Operating expenses	28.7		28.0		0.7		83.0		78.4		4.6
Depreciation and amortization	23.0		22.5		0.5		67.7		66.7		1.0
Operating income	38.8		31.8		7.0		80.6		69.3		11.3
Other income	1.1		2.3		(1.2)		3.3		4.8		(1.5)
Interest charges	(8.4)		(7.9)		(0.5)		(25.2)		(22.5)		(2.7)
Segment earnings before income taxes	31.6		26.1		5.5		58.7		51.6		7.1
Income (taxes)	(3.6)		(2.2)		(1.4)		(6.3)		(4.4)		(1.9)
Segment earnings	$	27.9	$	23.9	$	4.0	$	52.3	$	47.2	$	5.1

The following table shows total sales, including the impacts of weather, by retail tariff consumer class and average number of consumers:

	Three Months Ended September 30,				Nine Months Ended September 30,
			Percentage				Percentage
	2021	2020	Change		2021	2020	Change
Volumetric load (1) (GWh)	1,024.4	1,077.7	(4.9)	%	2,439.9	2,473.4	(1.4)	%
Demand-based load (2) (MW)	5,475.8	5,126.0	6.8	%	15,896.2	14,905.3	6.6	%
Average retail consumers (thousands) (3)	264.1	259.3	1.9	%	262.9	258.3	1.8	%

(1) Volumetric load consumers are billed on KWh usage.

(2) Demand-based load includes consumers billed on monthly KW peak and also includes retail transmission customers that are primarily billed under TNMP’s rate riders.

(3) TNMP provides transmission and distribution services to REPs that provide electric service to their customers in TNMP’s service territories. The number of consumers above represents the customers of these REPs. Under TECA, consumers in Texas have the ability to choose any REP to provide energy.

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Operating Results – Three Months Ended September 30, 2021 compared to 2020

The following table summarizes the significant changes to utility margin:

		Three Months Ended September 30, 2021
		Change
Utility margin:		(In millions)
	Transmission rate relief/load – Transmission cost of service rate increases in October 2020, March 2021, and September 2021 partially offset by lower wholesale transmission demand-based sales	$	4.2
	Distribution rate relief – Distribution cost of service rate established in September 2020 and increased in September 2021	4.2
	Volumetric-based consumer usage/load – Weather normalized KWh sales decreased 2.2%; the number of volumetric consumers increased 3.4%	(0.4)
	Demand-based consumer usage/load – Weather normalized demand-based MW sales for large commercial and industrial consumers excluding retail transmission consumers increased 2.8%	1.0
	Weather – Milder weather in 2021; cooling degree days were 2.9% lower in 2021	(0.9)
	Rate Riders and other– Impacts of rate riders, including the CTC surcharge which ended in August 2020, energy efficiency rider, rate case expense rider, and transmission cost recovery factor, which are offset in depreciation and amortization	0.2
	Net Change	$	8.3

The following tables summarize the primary drivers for changes in operating expenses, depreciation and amortization, other income (deductions), interest charges, and income taxes:

		Three Months Ended September 30, 2021
		Change
Operating expenses:		(In millions)
	Lower employee related, outside services, and vegetation management expenses	$	(0.7)
	Higher property taxes due to increased utility plant in service	0.5
	Lower capitalization of administrative and general and other expenses due to lower construction expenditures	0.7
	Other	0.2
	Net Change	$	0.7

Depreciation and amortization:
	Increased utility plant in service	$	2.7
	Decreased amortization of CTC, partially offset in utility margin	(2.2)
	Net Change	$	0.5

Other income (deductions):
	Lower equity AFUDC	$	(0.5)
	Lower CIAC	(0.6)
	Other	(0.1)
	Net Change	$	(1.2)

Interest charges:
	Issuance of $65.0 million first mortgage bonds in 2021	$	(0.2)
	Other	(0.3)
	Net Change	$	(0.5)

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		Three Months Ended September 30, 2021
		Change
Income (taxes) benefits:		(In millions)
	Higher segment earnings before income taxes	$	(1.1)
	Changes in the anticipated effective tax rate, including amortization of excess deferred income taxes. (Note 14)	(0.3)
	Net Change	$	(1.4)

Operating Results – Nine Months Ended September 30, 2021 compared to 2020

The following table summarizes the significant changes to utility margin:

		Nine Months Ended September 30, 2021
		Change
Utility margin:		(In millions)
	Transmission rate relief/load – Transmission cost of service rate increases in March 2020, October 2020, March 2021, and September 2021 partially offset by lower wholesale transmission demand-based sales	$	10.7
	Distribution rate relief – Distribution cost of service rate established in September 2020 and increased in September 2021	11.0
	Volumetric-based consumer usage/load – Weather normalized KWh sales decreased 1.0% in addition to the leap-year impact; the number of volumetric consumers increased 2.5%	(0.6)
	Demand-based consumer usage/load – Weather normalized demand-based MW sales for large commercial and industrial consumers excluding retail transmission consumers increased 2.4%	1.4
	Weather – Colder weather in the first quarter was partially offset by milder weather in the second and third quarters	0.2
	Rate Riders and other – Impacts of rate riders, including the CTC surcharge which ended in August 2020, energy efficiency rider, rate case expense rider, and transmission cost recovery factor, which are partially offset in operating expense and depreciation and amortization	(5.9)
	Net Change	$	16.8

The following tables summarize the primary drivers for changes in operating expenses, depreciation and amortization, other income (deductions), interest charges, and income taxes:

		Nine Months Ended September 30, 2021
		Change
Operating expenses:		(In millions)
	Higher employee related, outside services, and vegetation management expenses	$	2.9
	Higher property taxes due to increased utility plant in service	1.5
	Higher capitalization of administrative and general and other expenses due to higher construction expenditures	(0.5)
	Higher energy efficiency costs and amortization of rate expenses offset in utility margin	0.2
	Other	0.5
	Net Change	$	4.6

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		Nine Months Ended September 30, 2021
		Change
Depreciation and amortization:		(In millions)
	Increased utility plant in service	$	7.7
	Decreased amortization of CTC offset in utility margin	(6.8)
	Other	0.1
	Net Change	$	1.0

Other income (deductions):
	Lower equity AFUDC	$	(0.3)
	Lower CIAC	(1.1)
	Other	(0.1)
	Net Change	$	(1.5)

Interest charges:
	Issuance of $185.0 million first mortgage bonds in 2020	$	(2.4)
	Issuance of $65.0 million first mortgage bonds in 2021	(0.2)
	Other	(0.1)
	Net Change	$	(2.7)

Income (taxes) benefits:
	Higher segment earnings before income taxes	$	(1.5)
	Changes in the anticipated effective tax rate, including amortization of excess deferred income taxes. (Note 14)	(0.4)
	Net Change	$	(1.9)

Corporate and Other

The table below summarizes the operating results for Corporate and Other:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2021		2020		Change		2021		2020		Change
	(In millions)
Electric operating revenues	$	—	$	—	$	—	$	—	$	—	$	—
Cost of energy	—		—		—		—		—		—
Utility margin	—		—		—		—		—		—
Operating expenses	(4.1)		(4.9)		0.8		(6.4)		(14.6)		8.2
Depreciation and amortization	5.7		5.4		0.3		17.2		17.0		0.2
Operating income (loss)	(1.7)		(0.5)		(1.2)		(10.9)		(2.3)		(8.6)
Other income (deductions)	—		0.2		(0.2)		—		(0.8)		0.8
Interest charges	(2.3)		(4.6)		2.3		(9.7)		(14.8)		5.1
Segment earnings (loss) before income taxes	(4.0)		(4.9)		0.9		(20.5)		(17.8)		(2.7)
Income (taxes) benefit	2.5		3.5		(1.0)		6.0		5.8		0.2
Segment earnings (loss)	$	(1.5)	$	(1.5)	$	—	$	(14.5)	$	(12.0)	$	(2.5)

Corporate and Other operating expenses shown above are net of amounts allocated to PNM and TNMP under shared services agreements. The amounts allocated include certain expenses shown as depreciation and amortization and other income (deductions) in the table above. The change in operating expense for the three and nine months ended September 30, 2021 include an increase of $1.0 million and $8.2 million of costs related to the Merger that were not allocated to PNM or TNMP.

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Operating Results – Three Months Ended September 30, 2021 compared to 2020

The following tables summarize the primary drivers for changes in other income (deductions), interest charges, and income taxes:

		Three Months Ended September 30, 2021
		Change
Other income (deductions):		(In millions)
	Lower equity method investment income from NMRD	$	(0.1)
	Decrease in donations and other contributions	0.1
	Other	(0.2)
	Net Change	$	(0.2)

Interest charges:
	Lower interest on short-term borrowings	$	0.4
	Repayment of PNMR 2018 SUNs	2.6
	Higher interest on term loans	(0.8)
	Other	0.1
	Net Change	$	2.3

Income (taxes) benefits:
	Impact of difference in effective tax rates used by PNMR and its subsidiaries in the calculation of income taxes in interim periods	$	(0.6)
	Lower segment loss before income taxes	(0.2)
	Non-deductible merger related costs	(0.1)
	Other	(0.1)
	Net Change	$	(1.0)

Operating Results – Nine Months Ended September 30, 2021 compared to 2020

The following tables summarize the primary drivers for changes in other income (deductions), interest charges, and income taxes:

		Nine Months Ended September 30, 2021
		Change
Other income (deductions):		(In millions)
	Higher equity method investment income from NMRD	$	0.1
	Decrease in donations and other contributions	0.8
	Other	(0.1)
	Net Change	$	0.8

Interest charges:
	Higher interest on term loans	$	(2.3)
	Lower interest on short-term borrowings	1.6
	Repayment of PNMR 2018 SUNs	5.9
	Other	(0.1)
	Net Change	$	5.1

Income (taxes) benefits:
	Impact of difference in effective tax rates used by PNMR and its subsidiaries in the calculation of income taxes in interim periods	$	0.4
	Higher segment loss before income taxes	0.7
	Non-deductible merger related costs	(0.8)
	Other	(0.1)
	Net Change	$	0.2

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LIQUIDITY AND CAPITAL RESOURCES

Statements of Cash Flows

The changes in PNMR’s cash flows for the nine months ended September 30, 2021 compared to September 30, 2020 are summarized as follows:

	Nine Months Ended September 30,
	2021		2020		Change
	(In millions)
Net cash flows from (used in):
Operating activities	$	408.5	$	368.0	$	40.5
Investing activities	(503.8)		(527.4)		23.6
Financing activities	96.8		186.5		(89.7)
Net change in cash and cash equivalents	$	1.6	$	27.1	$	(25.5)

Cash Flows from Operating Activities

Changes in PNMR’s cash flow from operating activities result from net earnings, adjusted for items impacting earnings that do not provide or use cash. See Results of Operations above. Certain changes in assets and liabilities resulting from normal operations, including the effects of the seasonal nature of the Company’s operations, also impact operating cash flows.

Cash Flows from Investing Activities

The changes in PNMR’s cash flows used in investing activities relate primarily to changes in utility plant additions. Cash flows from investing activities include purchases and sales of investment securities in the NDT and coal mine reclamation trusts as well as activity related to NMRD. Major components of PNMR’s cash inflows and (outflows) from investing activities are shown below:

	Nine Months Ended September 30,
	2021		2020		Change
Cash (Outflows) for Utility Plant Additions	(In millions)
PNM:
Generation	$	(44.9)	$	(40.4)	$	(4.5)
Transmission and distribution	(188.1)		(194.4)		6.3
Nuclear fuel	(14.1)		(17.1)		3.0
	(247.1)		(251.9)		4.8
TNMP:
Transmission	(103.1)		(90.1)		(13.0)
Distribution	(130.3)		(138.9)		8.6
	(233.4)		(229.0)		(4.4)
Corporate and Other:
Computer hardware and software	(15.7)		(14.4)		(1.3)
Total cash (outflows) for additions to utility plant	$	(496.2)	$	(495.3)	$	(0.9)
Other Cash Flows from Investing Activities
Proceeds from sales of investment securities	$	757.6	$	489.2	$	268.4
Purchases of investment securities	(765.9)		(498.2)		(267.7)
Investments in NMRD	—		(23.3)		23.3
Distributions from NMRD	0.6		—		0.6
Other, net	0.1		0.2		(0.1)
Total cash (outflows) from investing activities	$	(503.8)	$	(527.4)	$	23.6

Cash Flows from Financing Activities

The changes in PNMR’s cash flows from financing activities include:

•Short-term borrowings decreased $18.1 million in 2021 compared to a decrease of $0.8 million in 2020, resulting in a net decrease in cash flows from financing activities of $17.3 million

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•In 2021, PNMR borrowed the remaining $220.0 million under the 2020 Delayed-Draw Term Loan and repaid $300.0 million SUNs

•In 2021, PNMR borrowed $850.0 million under the PNMR 2021 Delayed-Draw Term Loan and repaid the $150.0 million PNMR 2019 Term Loan, the $300.0 million PNMR 2020 Delayed-Draw Term Loan, the $150.0 million PNMR 2020 Term Loan, $92.1 million in borrowings under the PNMR Revolving Credit Facility, $40.0 million in borrowings under the PNMR Development Revolving Credit Facility, and the $65.0 million PNMR Development Term Loan

•In 2021, PNM entered into a $75.0 million term loan and used the funds to repay the PNM 2019 $40.0 million Term Loan and for other corporate purposes

•In 2021, TNMP issued $65.0 million aggregate principal amount of TNMP 2021 Bonds and used the proceeds to repay existing debt and for other corporate purposes

Financing Activities

See Note 7 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K and Note 9 for additional information concerning the Company’s financing activities. 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.

The Company’s ability to access the credit and capital markets at a reasonable cost is largely dependent upon its:

•Ability to earn a fair return on equity

•Results of operations

•Ability to obtain required regulatory approvals

•Conditions in the financial markets

•Credit ratings

The Company is closely monitoring developments and is taking steps to mitigate the potential risks related to COVID-19. The Company currently believes it has adequate liquidity but cannot predict the extent or duration of the outbreak, its effects on the global, national or local economy, including the Company's ability to access capital in the financial markets, or on the Company's financial position, results of operations, and cash flows.

Each of the Company’s revolving credit facilities and term loans contain a single financial covenant that requires the maintenance of a debt-to-capitalization ratio. For the PNMR 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. The Company is in compliance with its debt covenants.

At December 31, 2020, PNM had $146.0 million of outstanding PCRBs, which have a final maturity of April 1, 2033. These PCRBs were subject to mandatory tender on October 1, 2021 and were successfully remarketed to new investors on that date. The $146.0 million PCRBs bear interest at a fixed rate of 2.15% until their final maturity.

At December 31, 2020, PNM had $100.3 million of outstanding PNM Floating Rate PCRBs. The PNM Floating Rate PCRBs bore interest at rates that were reset weekly, giving investors the option to return the PCRBs for remarketing to new investors upon 7 days' notice. At September 30, 2021, this rate was 0.11%. On October 1, 2021 PNM converted the PNM Floating Rate PCRBs to the PNM 2021 Fixed Rate PCRBs. The PNM 2021 Fixed Rate PCRBs now bear interest at 0.875% and are subject to mandatory tender on October 1, 2026.

On September 23, 2021, PNM entered into the PNM September 2021 Note Purchase Agreement with institutional investors for the sale and issuance of $150.0 million aggregate principal amount of two series of the PNM September 2021 SUNs to be offered in private placement transactions. The PNM September 2021 SUNs will be issued on or before December 30, 2021. PNM will issue $50.0 million of the PNM September 2021 SUNs at 2.29%, due December 30, 2031, and another $100.0 million at 2.97%, due December 30, 2041. Proceeds from the PNM September 2021 SUNs will be used for funding of capital expenditures, including the purchase of the Western Spirit transmission line, repayment of existing indebtedness, and for general corporate purposes. The PNM September 2021 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 September 2021 SUNs at par. Although there are customary change of control provisions in the PNM debt agreements, the change of control provisions in these agreements, including the PNM September 2021 Note Purchase Agreement, are not triggered by the closing of the Merger. PNM has the right to redeem any or all of the PNM September 2021 SUNs prior to their maturities, subject to payment of a customary make-whole premium.

On July 14, 2021, TNMP entered the TNMP 2021 Bond Purchase Agreement with institutional investors for the sale of $65.0 million aggregate principal amount of the TNMP 2021 Bonds offered in private placement transactions. On August

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16, 2021, TNMP issued all $65.0 million of the TNMP 2021 Bonds at 2.44% with a maturity of August 15, 2035 and used the proceeds to repay existing debt and for other corporate purposes. The TNMP 2021 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the supplemental indenture governing the TNMP 2021 Bonds. The terms of the supplemental indenture governing the TNMP 2021 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 2021 Bonds at par. However, the definition of change of control in the supplemental indenture governing the TNMP 2021 Bonds will not be triggered by the closing of the Merger. TNMP has the right to redeem any or all of the TNMP 2021 Bonds prior to their maturity, subject to payment of a customary make-whole premium.

On July 14, 2021, PNM entered into the PNM 2021 Note Purchase Agreement with institutional investors for the sale and issuance of $160.0 million aggregate principal amount of the PNM 2021 SUNs offered in private placement transactions. The PNM 2021 SUNs were issued on July 14, 2021. PNM issued $80.0 million of the PNM 2021 SUNs at 2.59%, due July 15, 2033, and another $80.0 million at 3.14%, due July 15, 2041. Proceeds from the PNM 2021 SUNs were used to repay the total amount of $160.0 million of PNM's 5.35% SUNs, at par, earlier than their scheduled maturity of October 1, 2021. The PNM 2021 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 2021 SUNs at par. Although there are customary change of control provisions in the PNM debt agreements, the change of control provisions in these agreements, including the PNM 2021 Note Purchase Agreement, are not triggered by the closing of the Merger. PNM has the right to redeem any or all of the PNM 2021 SUNs prior to their maturities, subject to payment of a customary make-whole premium.

On June 18, 2021, PNM entered into the PNM 2021 Term Loan between PNM and Bank of America, N.A., as lender for $75.0 million. The PNM 2021 Term Loan was used to repay the PNM 2019 $40.0 million Term Loan and for other corporate purposes. The PNM 2021 Term Loan bears interest at a variable rate, which was 0.91% at September 30, 2021 and matures on December 18, 2022.

On May 18, 2021, PNMR entered into the PNMR 2021 Delayed-Draw Term Loan, among PNMR, the lenders party thereto, and Wells Fargo Bank, National Association, as administrative agent. Initially PNMR drew $850.0 million to repay and terminate existing indebtedness including the $150.0 million PNMR 2019 Term Loan, the $300.0 million PNMR 2020 Delayed-Draw Term Loan, the $150.0 million PNMR 2020 Term Loan, $92.1 million in borrowings under the PNMR Revolving Credit Facility, the $65.0 million PNMR Development Term Loan, and $40.0 million in borrowings under the PNMR Development Revolving Credit Facility, which was then terminated. Draws on the PNMR 2021 Delayed-Draw Term Loan bear interest at a variable rate, which was 0.94% at September 30, 2021, and mature on May 18, 2023.

The PNMR 2021 Delayed-Draw Term Loan provides that substantially concurrently with the consummation of the transactions set forth in the Merger Agreement, PNMR will assign to Avangrid all of its rights, duties, obligations and liabilities under the PNMR 2021 Delayed-Draw Term Loan and Avangrid will assume from PNMR, as its direct and primary obligation, the payment and performance of all of the duties, liabilities and obligations of PNMR under the PNMR 2021 Delayed-Draw Term Loan pursuant to an amendment and restatement of the PNMR 2021 Delayed-Draw Term Loan in the form of an amended and restated credit agreement attached to the PNMR 2021 Delayed-Draw Term Loan.

On March 9, 2018, PNMR issued $300.0 million aggregate principal amount of 3.25% SUNs (the “PNMR 2018 SUNs”), which were set to mature on March 9, 2021. On December 22, 2020, PNMR entered into the $300.0 million PNMR 2020 Delayed-Draw Term Loan that would have matured in January 2022 and drew $80.0 million to refinance existing indebtedness and for other corporate purposes. On March 9, 2021, PNMR utilized the remaining $220.0 million of capacity under the PNMR 2020 Delayed-Draw Term Loan to repay an equivalent amount of the PNMR 2018 SUNs. The remaining $80.0 million repayment of the PNMR 2018 SUNs was funded through borrowings under the PNMR Revolving Credit Facility.

In August 2020, PNMR entered into the WFB LOC Facility aggregating $30.3 million that was issued to facilitate the posting of reclamation bonds currently held by WSJ LLC (who assumed all the obligations of SJCC post-bankruptcy). The reclamation bonds were required to be posted in connection with permits relating to the operation of the San Juan mine. See Note 11.

On October 20, 2020, the execution of the Merger Agreement constituted a “Change of Control” under certain PNMR, TNMP, and PNMR Development debt agreements. Under each of the specified debt agreements, a “Change of Control” constitutes an “Event of Default,” pursuant to which the lender parties thereto had the right to accelerate the indebtedness under the debt agreements. The definition of Change of Control under the PNM debt agreements and PNM note purchase agreements was not triggered by the execution of the Merger Agreement.

On October 26, 2020, PNMR, TNMP and PNMR Development entered into amendment agreements with the lender parties thereto to amend the definition of "Change of Control" such that the entry into the Merger Agreement would not constitute a Change of Control and to waive the Event of Default arising from entry into the Merger Agreement. On September 15, 2021, PNMR and TNMP entered into amendment agreements with the lender parties thereto to further amend the definition of "Change of Control" such that the closing of the Merger does not constitute a Change of Control. The Change of Control

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provisions in the PNM debt agreements, PNM note purchase agreements, and TNMP 2021 Bond Purchase Agreement are not triggered by the closing of the Merger and did not require amendment.

The documents governing TNMP's aggregate $750.0 million of outstanding 2014 to 2020 First Mortgage Bonds ("TNMP FMBs") obligated TNMP to offer, within 30 business days following the signing of the Merger Agreement, to prepay all $750.0 million outstanding TNMP FMBs at 100% of the principal amount, plus accrued and unpaid interest thereon, but without any make-whole amount or other premium. TNMP made such offer to prepay the TNMP FMBs in accordance with the terms of the TNMP FMBs, and none of the holders of the TNMP FMBs accepted TNMP’s offer. The documents governing the 2014 to 2020 TNMP FMBs require TNMP to make another offer, within 30 business days of closing of the Merger, to prepay all $750.0 million outstanding TNMP FMBs at par. TNMP will make such offer to prepay all $750.0 million outstanding TNMP FMBs in accordance with the terms of the TNMP FMBs; however, holders of the TNMP FMBs are not required to tender their TNMP FMBs and may accept or reject such offer to prepay. As discussed above, the supplemental indenture that governs the TNMP 2021 Bonds excludes the Merger from the definition of Change of Control.

The TNMP FMBs are not registered under the Securities Act and may not be offered or sold in the United States absent registration or applicable exemption from registration requirements and applicable state laws. The information in this Quarterly Report on Form 10-Q is for informational purposes only and is neither an offer to purchase, nor a solicitation of an offer to sell, subscribe for or buy any securities in any jurisdiction pursuant to the proposed transactions or otherwise, nor shall there be any sale, issuance or transfer of securities in any jurisdiction in contravention of applicable law. Similar to the offer to prepay made after signing the Merger Agreement, the post-Merger closing offer to prepay the TNMP FMBs will be made only pursuant to an offer to prepay, which will set forth the terms and conditions of the offer to prepay.

In 2017, PNMR entered into three separate four-year hedging agreements whereby it effectively established fixed interest rates on three separate tranches, each of $50.0 million, of its variable rate debt. The hedging agreements effectively fixed interest rates on the aggregate $150.0 million of short-term debt at rates of 1.926%, 1.823%, and 1.629%, plus customary spreads over LIBOR, and were subject to changes if there was a change in PNMR’s credit rating. On March 23, 2021, the 1.926% fixed interest rate hedge agreement expired according to its terms and the remaining agreements expired on May 23, 2021. See Note 9.

Capital Requirements

PNMR’s total capital requirements consist of construction expenditures, cash dividend requirements for PNMR common stock and PNM preferred stock, and capital contributions for PNMR Development’s 50% ownership interest in NMRD. Key activities in PNMR’s current construction program include:

•Investments in transmission and distribution infrastructure

•Upgrading generation resources and delivering clean energy

•Purchasing nuclear fuel

Projected capital requirements, including amounts expended through September 30, 2021, are:

	2021		2022-2025		Total
	(In millions)
Construction expenditures	$	1,045.4	$	2,939.8	$	3,985.2
Dividends on PNMR common stock	112.4		449.8		562.2
Dividends on PNM preferred stock	0.5		2.1		2.6
Total capital requirements	$	1,158.3	$	3,391.7	$	4,550.0

The construction expenditure estimates are under continuing review and subject to ongoing adjustment, as well as to Board review and approval. The construction expenditures above include a net investment of $301.2 million in 2021 resulting from PNM’s agreement to purchase the Western Spirit Line, subject to certain conditions being met prior to closing. Also included in the table above are expenditures for PNM’s Wired for the Future capital initiative that includes investments in transmission and distribution infrastructure to deliver clean energy, enhance customer satisfaction, and increase grid resilience. Not included in the table above are potential future contributions to NMRD and incremental expenditures for new customer growth in New Mexico and Texas, and other transmission and renewable energy expansion in New Mexico. The ability of PNMR to pay dividends on its common stock is dependent upon the ability of PNM and TNMP to pay dividends to PNMR and the Merger (See Note 18). Note 6 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K describes regulatory and contractual restrictions on the payment of dividends by PNM and TNMP.

During the nine months ended September 30, 2021, PNMR met its capital requirements and construction expenditures through cash generated from operations, as well as its liquidity arrangements and the borrowings discussed in Financing Activities above.

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In addition to the capital requirements for construction expenditures and dividends, the Company has long-term debt and term loans that must be paid or refinanced at maturity. PNM has $104.5 million of PCRBs that must be repriced in June 2022. See Note 9 for additional information about the Company’s long-term debt and equity arrangements. The Company may also enter into new arrangements similar to the existing agreements, borrow under the revolving credit facilities, or issue new long-term debt or equity in the public or private capital markets, or a combination of these sources. The Company has from time to time refinanced or repurchased portions of its outstanding debt before scheduled maturity. Depending on market conditions, the Company may refinance other debt issuances or make additional debt repurchases in the future.

Liquidity

PNMR’s liquidity arrangements include the PNMR Revolving Credit Facility, the PNM Revolving Credit Facility, and the TNMP Revolving Credit Facility. The PNMR and PNM facilities currently expire in October 2023 but can be extended through October 2024, subject to approval by a majority of the lenders. The $75.0 million TNMP Revolving Credit Facility matures in September 2022 and contains two one-year extension options, subject to approval by a majority of the lenders. PNM also has the $40.0 million PNM 2017 New Mexico Credit Facility that expires in December 2022. The Company believes the terms and conditions of these facilities are consistent with those of other investment grade revolving credit facilities in the utility industry.  Variable interest rates under these facilities are based on LIBOR but contain provisions which allow for the replacement of LIBOR with other widely accepted interest rates. The Company expects that it will be able to extend or replace these credit facilities under similar terms and conditions prior to their expirations.

The revolving credit facilities and the PNM 2017 New Mexico Credit Facility provide short-term borrowing capacity. The revolving credit facilities also allow letters of credit to be issued. Letters of credit reduce the available capacity under the facilities. The Company utilizes these credit facilities and cash flows from operations to provide funds for both construction and operational expenditures. The Company’s business is seasonal with more revenues and cash flows from operations being generated in the summer months. In general, the Company relies on the credit facilities to be the initial funding source for construction expenditures. Accordingly, borrowings under the facilities may increase over time. Depending on market and other conditions, the Company will periodically sell long-term debt and use the proceeds to reduce the borrowings under the credit facilities.

Information regarding the range of borrowings for each facility is as follows:

	Three Months Ended September 30, 2021				Nine Months Ended September 30, 2021
Range of Borrowings	Low		High		Low		High
	(In millions)
PNM:
PNM Revolving Credit Facility	$	—	$	—	$	—	$	37.2
PNM 2017 New Mexico Credit Facility	—		—		—		10.0
TNMP Revolving Credit Facility	—		67.0		—		70.0
PNMR Revolving Credit Facility	13.9		81.5		10.2		134.5
PNMR Development Revolving Credit Facility	—		—		—		40.0

At September 30, 2021, the weighted average interest rates were 1.58% for the PNMR Revolving Credit Facility. There were no borrowings outstanding under the PNM Revolving Credit Facility, the PNM 2017 New Mexico Revolving Credit Facility, or the TNMP Revolving Credit Facility at September 30, 2021.

The Company currently believes that its capital requirements for at least the next twelve months can be met through internal cash generation, existing, extended, or new credit arrangements, and access to public and private capital markets as discussed above and in Note 9. The Company anticipates that it may be necessary to obtain additional long-term financing to fund its capital requirements and to balance its capital structure during the 2021-2025 period. This could include new debt and/or equity issuances. To cover the difference in the amounts and timing of internal cash generation and cash requirements, the Company intends to use short-term borrowings under its current and future liquidity arrangements or other short-term loans. However, if market conditions worsen, the Company may not be able to access the capital markets or renew credit facilities when they expire or the cost of these facilities and debt issuances may increase. Should that occur, the Company would seek to improve cash flows by reducing capital expenditures and exploring other available alternatives.

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As of October 22, 2021, ratings on the Company’s securities were as follows:

	PNMR	PNM	TNMP
S&P
Issuer rating	BBB	BBB	BBB+
Senior secured debt	*	*	A
Senior unsecured debt	BBB-	BBB	*
Preferred stock	*	BB+	*
Moody’s
Issuer rating	Baa3	Baa2	A3
Senior secured debt	*	*	A1
Senior unsecured debt	Baa3	Baa2	*
* Not applicable

Currently, all of the credit ratings issued by both Moody’s and S&P on the Company’s debt are investment grade. Investors are cautioned that a security rating is not a recommendation to buy, sell, or hold securities, that each rating is subject to revision or withdrawal at any time by the rating organization, and that each rating should be evaluated independently of any other rating.

A summary of liquidity arrangements as of October 22, 2021 is as follows:

	PNM		TNMP		PNMR Separate		PNMR Consolidated
	(In millions)
Financing capacity:
Revolving credit facility	$	400.0	$	75.0	$	300.0	$	775.0
PNM 2017 New Mexico Credit Facility	40.0		—		—		40.0
Total financing capacity	$	440.0	$	75.0	$	300.0	$	815.0
Amounts outstanding as of October 22, 2021:
Revolving credit facility	$	—	$	—	$	10.6	$	10.6
PNM 2017 New Mexico Credit Facility	—		—		—		—
Letters of credit	2.2		—		3.4		5.6
Total short-term debt and letters of credit	2.2		—		14.0		16.2
Remaining availability as of October 22, 2021	$	437.8	$	75.0	$	286.0	$	798.8
Invested cash as of October 22, 2021	$	61.8	$	11.4	$	0.9	$	74.1

In addition to the above, PNMR has $30.3 million of letters of credit issued under the WFB LOC Facility. See Note 9. The above table excludes intercompany debt. As of October 22, 2021, PNM and TNMP had no borrowings from PNMR under their intercompany loan agreements however, PNMR Development had $0.2 million in borrowings from PNMR. PNMR had no intercompany borrowings from PNM, TNMP, or PNMR Development. The remaining availability under the revolving credit facilities at any point in time varies based on a number of factors, including the timing of collections of accounts receivables and payments for construction and operating expenditures.

PNM has a shelf registration statement for up to $650.0 million of senior unsecured notes that expires in May 2023.

Off-Balance Sheet Arrangements

PNMR has no off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that are material to investors.

Commitments and Contractual Obligations

PNMR, PNM, and TNMP have contractual obligations for long-term debt, leases, construction expenditures, purchase obligations, and certain other long-term obligations. See MD&A – Commitments and Contractual Obligations in the 2020 Annual Reports on Form 10-K. See Note 13 for further details regarding the PVNGS leases.

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Contingent Provisions of Certain Obligations

As discussed in the 2020 Annual Reports on Form 10-K, PNMR, PNM, and TNMP have a number of debt obligations and other contractual commitments that contain contingent provisions. Some of these, if triggered, could affect the liquidity of the Company. In the unlikely event that the contingent requirements were to be triggered, PNMR, PNM, or TNMP could be required to provide security, immediately pay outstanding obligations, or be prevented from drawing on unused capacity under certain credit agreements. The contingent provisions also include contractual increases in the interest rate charged on certain of the Company’s short-term debt obligations in the event of a downgrade in credit ratings. The Company believes its financing arrangements are sufficient to meet the requirements of the contingent provisions. No conditions have occurred that would result in any of the above contingent provisions being implemented.

Capital Structure

The capitalization tables below include the current maturities of long-term debt, but do not include short-term debt and do not include lease obligations as debt.

	September 30, 2021		December 31, 2020
PNMR
PNMR common equity	37.9	%	38.3	%
Preferred stock of subsidiary	0.2		0.2
Long-term debt	61.9		61.5
Total capitalization	100.0	%	100.0	%
PNM
PNM common equity	52.0	%	51.4	%
Preferred stock	0.3		0.3
Long-term debt	47.7		48.3
Total capitalization	100.0	%	100.0	%
TNMP
Common equity	50.3	%	49.2	%
Long-term debt	49.7		50.8
Total capitalization	100.0	%	100.0	%

OTHER ISSUES FACING THE COMPANY

Climate Change Issues

Background

For the past several years, management has identified multiple risks and opportunities related to climate change, including potential environmental regulation, technological innovation, and availability of fuel and water for operations, as among the most significant risks facing the Company. Accordingly, these risks are overseen by the Board in order to facilitate more integrated risk and strategy oversight and planning. Board oversight includes understanding the various challenges and opportunities presented by these risks, including the financial consequences that might result from enacted and potential federal and/or state regulation of GHG; plans to mitigate these risks; and the impacts these risks may have on the Company’s strategy. In addition, the Board approves certain procurements of environmental equipment, grid modernization technologies, and replacement generation resources.

Management is also responsible for assessing significant risks, developing and executing appropriate responses, and reporting to the Board on the status of risk activities. For example, management periodically updates the Board on the implementation of corporate environmental policy, and the Company’s environmental management systems, including the promotion of energy efficiency programs, and the use of renewable resources.  The Board is also informed of the Company’s practices and procedures to assess the impacts of operations on the environment. The Board considers issues associated with climate change, the Company’s GHG exposures, and the financial consequences that might result from enacted and potential federal and/or state regulation of GHG. Management has published, with Board oversight, a Climate Change Report available at http://www.pnmresources.com/about-us/sustainability-portal.aspx, that details the Company’s efforts to transition to an emissions-free generating portfolio by 2040.

As part of management’s continuing effort to monitor climate-related risks and assess opportunities, the Company has advanced its understanding of climate change by participating in the “2 Degree Scenario” planning by participating in the Electric Power Research Institute (“EPRI”) Understanding Climate Scenarios & Goal Setting Activities program. The program

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focused on characterizing and analyzing the relationship of individual electric utility company’s carbon emissions and global temperature goals. Activities include analyzing the scientific understanding of global emissions pathways that are consistent with limiting global warming and providing insight to assist companies in developing approaches to climate scenario planning. As PNM expands its sustainability efforts, EPRI’s program has also been useful in gaining a better understanding of the Task Force on Climate-Related Financial Disclosures’ (“TCFD”) recommendations for sustainability reporting. On November 19, 2019, TCFD announced the formation of the TCFD Advisory Group on Climate-Related Guidance. EPRI was invited to participate as one of seven members of the group that will provide guidance on implementing scenario analysis at the utility company level and to assist in understanding how climate-related issues affect business strategies.

The Company cannot anticipate or predict the potential long-term effects of climate change or climate change related regulation on its results of operations, financial position, or cash flows.

Greenhouse Gas Emissions Exposures

In 2020, GHG associated with PNM’s interests in its fossil-fueled generating plants included approximately 5.4 million metric tons of CO2, which comprises the vast majority of PNM’s GHG.

As of September 30, 2021, approximately 56% of PNM’s generating capacity, including resources owned, leased, and under PPAs, all of which is located within the U.S., consisted of coal or gas-fired generation that produces GHG. This reflects the retirement of SJGS Units 2 and 3 that occurred in December 2017 and the restructuring of ownership in SJGS Unit 4. These events reduced PNM’s entitlement in SJGS from 783 MW to 562 MW and caused the Company’s output of GHG to decrease when compared to 2017. Many factors affect the amount of GHG emitted, including total electricity sales, plant performance, economic dispatch, and the availability of renewable resources. For example, wind generation performance from PNM’s largest single renewable energy resource, New Mexico Wind, varies each year as a result of highly seasonal wind patterns and annual wind resource variability. Similarly, if PVNGS experienced prolonged outages or if PNM’s entitlement from PVNGS were reduced, PNM might be required to utilize other power supply resources such as gas-fired generation, which could increase GHG.

PNM has several programs underway to reduce or offset GHG from its generation resource portfolio, thereby reducing its exposure to climate change regulation. As described in Note 16 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K, PNM received approval for the December 31, 2017 shutdown of SJGS Units 2 and 3 as part of its strategy to address the regional haze requirements of the CAA. The shutdown of SJGS Units 2 and 3 resulted in a reduction of GHG for the entire station of approximately 54% for 2018, reflecting a reduction of 32% of GHG from the Company’s owned interests in SJGS, below 2005 levels. In 2020, PNM received authorization for a June 2022 abandonment of SJGS Units 1 and 4. In addition, PNM has filed a request with the NMPRC for approval to sell its ownership interest in Four Corners by the end of 2024. See additional discussion of the SJGS and Four Corners Abandonment in Note 12. If approved by the NMPRC, retiring PNM’s share of SJGS and exiting participation in Four Corners would further reduce PNM’s GHG as those two coal-fired stations represent approximately 84% of PNM's 2019 GHG emissions from generation.

As of September 30, 2021, PNM owns or procures power under PPAs from 957 MW of capacity from renewable generation resources. This is comprised of solar-PV, wind, and geothermal facilities including 158 MW of PNM-owned solar, 130 MW of solar-PV capacity which serve a data center located in PNM's service territory and 140 MW of wind which began commercial operations in 2021 to serve retail customers. This renewable capacity will increase to 1,057 MW by the first quarter of 2022 with an anticipated 100 MW of solar-PV scheduled to come online in the first quarter of 2022. Finally, the entire portfolio of replacement resources approved by the NMPRC on July 29, 2020, in PNM’s SJGS Abandonment Application, includes replacement of SJGS capacity with procurement of 650 MW of solar PPAs combined with 300 MW of battery storage agreements. These resources will result in PNM owning, leasing, or procuring through PPAs, capacity from renewable resources and battery storage facilities totaling 2,007 MW by year-end 2022. PNM has also filed two other requests with the NMPRC for authorization to procure future additional renewable energy resources. In the PVNGS Leased Interest Abandonment Application PNM requested authorization to procure 450 MW of solar capacity and 290 MW of battery energy storage resources as replacement for the leased PVNGS capacity of 114 MW and to assure system reliability. PNM has also been authorized to procure an additional 240 MW of solar capacity and 50 MW of battery energy storage to serve the Facebook data center located in PNM’s service territory. Approval of these renewable energy and battery resources should further reduce any exposure to GHG emissions risk. These estimates are subject to change due to underlying variables, including changes in PNM's generation portfolio, supplier's ability to meet contractual in-service dates and complex relationships between several factors. See additional discussion of these resources in Notes 11 and 12.

PNM also has a customer distributed solar generation program that represented 190.8 MW at September 30, 2021. PNM’s distributed solar programs will generate an estimated 381.6 GWh of emission-free solar energy available this year to offset PNM’s annual production from fossil-fueled electricity generation. PNM has offered its customers a comprehensive portfolio of energy efficiency and load management programs since 2007. PNM’s cumulative savings from these programs was approximately 5,206 GWh of electricity through 2020. Over the next 20 years, PNM projects energy efficiency and load management programs will provide the equivalent of approximately 9,500 GWh of electricity savings, which will avoid at least

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1.0 million metric tons of CO2 based upon projected emissions from PNM’s system-wide resources. These estimates are subject to change because of the uncertainty of many of the underlying variables, including changes in PNM’s generation portfolio, demand for electricity, energy efficiency, and complex relationships between those variables.

Because of PNM’s dependence on fossil-fueled generation, legislation or regulation that imposes a limit or cost on GHG could impact the cost at which electricity is produced. While PNM expects to recover any such costs through rates, the timing and outcome of proceedings for cost recovery are uncertain. In addition, to the extent that any additional costs are recovered through rates, customers may reduce their usage, relocate facilities to other areas with lower energy costs, or take other actions that ultimately could adversely impact PNM.

Other Climate Change Risks

PNM’s generating stations are located in the arid southwest. Access to water for cooling for some of these facilities is critical to continued operations. Forecasts for the impacts of climate change on water supply in the southwest range from reduced precipitation to changes in the timing of precipitation. In either case, PNM’s generating facilities requiring water for cooling will need to mitigate the impacts of climate change through adaptive measures. Current measures employed by PNM generating stations such as air cooling, use of grey water, improved reservoir operations, and shortage sharing arrangements with other water users will continue to be important to sustain operations.

PNM’s service areas occasionally experience periodic high winds and severe thunderstorms. TNMP has operations in the Gulf Coast area of Texas, which experiences periodic hurricanes and other extreme weather conditions. In addition to potentially causing physical damage to Company-owned facilities, which disrupts the ability to transmit and/or distribute energy, weather and other events of nature can temporarily reduce customers’ usage and demand for energy. In addition, other events influenced by climate change, such as wildfires, could disrupt Company operations or result in third-party claims against the Company.

EPA Regulation

In April 2007, the US Supreme Court held that EPA has the authority to regulate GHG under the CAA.  This decision heightened the importance of this issue for the energy industry.  In December 2009, EPA released its endangerment finding for GHG from new motor vehicles, stating that the atmospheric concentrations of six key greenhouse gases (CO2, methane, nitrous oxides, hydrofluorocarbons, perfluorocarbons, and sulfur hexafluoride) endanger the public health and welfare of current and future generations. In May 2010, EPA released the final Prevention of Significant Deterioration (“PSD”) and Title V Greenhouse Gas Tailoring Rule to address GHG from stationary sources under the CAA permitting programs. The purpose of the rule was to “tailor” the applicability of two programs, the PSD construction permit and Title V operating permit programs, to avoid impacting millions of small GHG emitters. On June 23, 2014, the US Supreme Court found EPA lacked authority to “tailor” the CAA’s unambiguous numerical thresholds of 100 or 250 tons per year, and thus held EPA may not require a source to obtain a PSD permit solely on the basis of its potential GHG. However, the court upheld EPA’s authority to apply the PSD program for GHG to “anyway” sources - those sources that are required to comply with the PSD program for other non-GHG pollutants.

On June 25, 2013, then President Obama announced his Climate Action Plan, which outlined how his administration planned to cut GHG in the U.S., prepare the country for the impacts of climate change, and lead international efforts to combat and prepare for global warming. The plan proposed actions that would lead to the reduction of GHG by 17% below 2005 levels by 2020.

On August 3, 2015, EPA responded to the Climate Action Plan by issuing three separate but related actions, which were published in October 2015: (1) the Carbon Pollution Standards for new, modified, and reconstructed power plants (under Section 111(b)); (2) the Clean Power Plan for existing power plants (under Section 111(d)); and (3) a proposed federal plan associated with the Clean Power Plan.

EPA’s Carbon Pollution Standards for new sources (those constructed after January 8, 2014) established separate standards for gas and coal-fired units. The standards reflect the degree of emission limitation achievable through the application of what EPA determined to be the BSER demonstrated for each type of unit. For newly constructed and reconstructed base load natural gas-fired stationary combustion turbines, EPA finalized a standard based on efficient natural gas combined cycle technology. The final standards for coal-fired power plants vary depending on whether the unit is new, modified, or reconstructed, but the new unit standards were based on EPA’s determination that the BSER for new units was partial carbon capture and sequestration. The Clean Power Plan established numeric “emission standards” for existing electric generating units - one for “fossil-steam” units (coal and oil-fired units) and one for natural gas-fired units (combined cycle only). The emission standards were based on emission reduction opportunities that EPA deemed achievable using technical assumptions for three “building blocks”: efficiency improvements at coal-fired EGUs, displacement of affected EGUs with renewable energy, and displacement of coal-fired generation with natural gas-fired generation.

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Multiple states, utilities, and trade groups filed petitions for review in the DC Circuit to challenge both the Carbon Pollution Standards for new sources and the Clean Power Plan for existing sources, and the challenges successfully petitioned the US Supreme Court for a stay of the Clean Power Plan. However, before the DC Circuit could issue an opinion regarding either the Carbon Pollution Standards or the Clean Power Plan, President Trump took office and his administration asked the court to hold both cases in abeyance while the rules were re-evaluated, which the court granted.

On June 19, 2019, EPA repealed the Clean Power Plan, promulgated the ACE Rule, and revised the implementing regulations for all emission guidelines issued under CAA Section 111(d). EPA set the BSER for existing coal-fired power plants as heat rate efficiency improvements based on a range of “candidate technologies” to be applied inside the fence-line. Rather than setting a specific numerical standard of performance, EPA’s rule directed states to determine which of the candidate technologies to apply to each coal-fired unit and to establish standards of performance based on the degree of emission reduction achievable based on the application of BSER.

While corresponding NSR reform regulations were proposed as part of the proposed ACE Rule, the final rule did not include such reform measures. Unrelated to the ACE Rule, EPA issued a proposed rule on August 1, 2019 to clarify one aspect of the pre-construction review process for evaluating whether the NSR permitting program would apply to a proposed project at an existing source of emissions. The final rule on NSR Project Emissions Accounting became effective on December 24, 2020 clarifying that both emissions increases and decreases resulting from a project are to be considered in determining whether the proposed project will result in an increase in air emissions. The Biden Administration denied a petition for reconsideration of the rule on October 12, 2021 but indicated that it plans to initiate a new rulemaking to address the issues raised by the petitioners.

On January 19, 2021, the DC Circuit issued an opinion in American Lung Association and American Public Health Association v. EPA, et al. regarding challenges to the EPA’s ACE Rule regulating emissions of carbon dioxide from EGUs under section 111(d) of the Clean Air Act. The DC Circuit vacated the ACE Rule and remanded the record to EPA for further consideration consistent with the court’s opinion, finding that EPA misinterpreted the Clean Air Act when it determined that the language of section 111 unambiguously barred consideration of emissions reductions options that were not applied at the source. Four petitions for certiorari to the US Supreme Court were filed, followed by several supporting briefs, and EPA filed its response on August 5, 2021, and a briefing was completed on August 24, 2021.

EPA filed a motion seeking a partial stay of the mandate as to the repeal of the Clean Power Plan, to ensure the court’s order will not render effective the now out-of-date Clean Power Plan. On February 22, 2021, the U.S. Court of Appeals for the DC Circuit granted EPA’s motion, indicating that it would withhold issuance of the mandate with respect to the repeal of the Clean Power Plan until EPA responds to the court’s remand in a new rulemaking action. 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 the Biden Administration is unlikely to finalize the revisions proposed in 2018 and that reconsideration of the rule has concluded.

On January 20, 2021, President Biden signed an executive order “Protecting Public Health and the Environment and Restoring Science to Tackle the Climate Crisis,” which instructs agency heads to review all Trump Administration actions for inconsistency with the Biden Administration’s policy “to listen to the science; to improve public health and protect our environment; to ensure access to clean air and water; to limit exposure to dangerous chemicals and pesticides; to hold polluters accountable, including those who disproportionately harm communities of color and low-income communities; to reduce greenhouse gas emissions; to bolster resilience to the impacts of climate change; to restore and expand our national treasures and monuments; and to prioritize both environmental justice and the creation of the well-paying union jobs necessary to deliver on these goals.” Agency heads were directed to consider suspending, revising or rescinding any action that is inconsistent with the stated policy. Within 30 days of the executive order, agency heads submitted to OMB a preliminary list of those actions being considered for suspension, revision or rescission that would be completed by December 31, 2021, and would be subject to OMB review. Within 90 days of the executive order, agency heads submitted to OMB an updated list of such actions that would be completed by December 31, 2025. EPA is reconsidering the ACE Rule pursuant to this executive order.

Federal Legislation

President Biden has indicated that climate change is a top priority for his administration. A number of legislative proposals to address climate change are already being considered in the Democratic-led U.S. House of Representatives, but the thin majority held by the Democrats in the Senate may make enactment of new laws to address climate change difficult. 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.

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State and Regional Activity

Pursuant to New Mexico law, each utility must submit an IRP to the NMPRC every three years to evaluate renewable energy, energy efficiency, load management, distributed generation, and conventional supply-side resources on a consistent and comparable basis.  The IRP is required to take into consideration risk and uncertainty of fuel supply, price volatility, and costs of anticipated environmental regulations when evaluating resource options to meet supply needs of the utility’s customers.  The NMPRC requires that New Mexico utilities factor a standardized cost of carbon emissions into their IRPs using prices ranging between $8 and $40 per metric ton of CO2 emitted and escalating these costs by 2.5% per year.  Under the NMPRC order, each utility must analyze these standardized prices as projected operating costs.  Reflecting the evolving nature of this issue, the NMPRC order states that these prices may be changed in the future to account for additional information or changed circumstances.  Although these prices may not reflect the costs that ultimately will be incurred, PNM is required to use these prices for purposes of its IRP.  In its 2020 filing for Four Corners Abandonment, PNM analyzed resource portfolio plans for scenarios that assumed Four Corners will operate through 2031 and for scenarios that assumed PNM will exit Four Corners at the end of 2024. The key findings of the analysis include that exiting Four Corners in 2024 would provide long-term economic benefits to PNM’s customers. See Note 12.

The ETA was signed into New Mexico state law and became effective on June 14, 2019. The ETA, among other things, requires that investor-owned utilities obtain specified percentages of their energy from renewable and carbon-free resources. Prior to the enactment of the ETA, the REA established a mandatory RPS requiring utilities to acquire a renewable energy portfolio equal to 10% of retail electric sales by 2011, 15% by 2015, and 20% by 2020. The ETA amends the REA and requires utilities operating in New Mexico to have renewable portfolios equal to 20% by 2020, 40% by 2025, 50% by 2030, 80% by 2040, and 100% zero-carbon energy by 2045. Under the ETA provisions, PNM will also be required to meet a generation emission standard of no more than 400 lbs. of CO2 per MWh beginning in 2023 and not more than 200 lbs. per MWh beginning in 2032. PNM takes this requirement into account in its resource planning and it is expected that the standards will be met with the proposed resource retirements and replacements. The ETA provides for a transition from coal-fired generating resources to carbon-free resources by allowing investor-owned utilities to issue securitized bonds, or “energy transition bonds,” related to the retirement of coal-fired generating facilities to qualified investors. Proceeds from the 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 coal mine decommissioning, plant decommissioning, and other costs that have not yet been charged to customers or disallowed by the NMPRC or by a court order. Proceeds provided by energy transition bonds may also be used to pay for severances for employees of the retired coal-fired generating facility and related coal mine, as well as to pay for job training, education, and economic development. Energy transition bonds must be issued under a NMPRC financing order and are paid by a non-bypassable charge paid by all customers of the issuing utility. The ETA also amends sections of the REA to allow 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 prioritize replacement resources in a manner intended to mitigate the economic impact to communities affected by these plant retirements. See additional discussion of the ETA in Note 11. PNM expects the ETA will have a significant impact on PNM’s future generation portfolio. In February 2020, the hearing examiners assigned to the SJGS abandonment and financing proceedings issued recommended decisions recommending approval of PNM’s abandonment application and for the issuance of Securitized Bonds consistent with the requirements of the ETA. On April 1, 2020, the NMPRC approved the hearing examiners' recommendation to approve PNM's application to retire its share of SJGS in 2022 and for the issuance of Securitized Bonds. See additional discussion of PNM’s SJGS Abandonment Application in Note 12. PNM has also requested approval of energy transition bonds for the Four Corners Abandonment costs of that transition away from coal-fired generation. PNM cannot predict the full impact of the ETA or the outcome of potential future generating resource abandonment filings with the NMPRC.

International Accords

The United Nations Framework Convention on Climate Change (“UNFCCC”) is an international environmental treaty that was negotiated at the 1992 United Nations Conference on Environment and Development (informally known as the Earth Summit) and entered into force in March 1994.  The objective of the treaty is to “stabilize greenhouse gas concentrations in the atmosphere at a level that would prevent dangerous anthropogenic interference with the climate system.”  Parties to the UNFCCC, including the U.S., have been meeting annually in Conferences of the Parties (“COP”) to assess progress in meeting the objectives of the UNFCCC. 

On December 12, 2015, the Paris Agreement was finalized during the 2015 COP. The aim of the Paris Agreement is to limit global temperature rise to two degrees Celsius above pre-industrial levels. The agreement, which was agreed to by approximately 200 parties, requires that countries submit INDCs. INDCs reflect national targets and actions that arise out of national policies and elements relating to oversight, guidance and coordination of actions to reduce emissions by all countries. In November 2014, then President Obama announced the United States’ commitment to reduce GHG, on an economy-wide basis, by 26%-28% from 2005 levels by the year 2025. The U.S. INDC was part of an overall effort by the former administration to have the U.S. achieve economy-wide reductions of around 80% by 2050.  The former administration’s GHG reduction target for the electric utility industry was a key element of its INDC and was based on EPA’s GHG regulations for

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new, existing, and modified and reconstructed sources at that time. Thresholds for the number of countries necessary to ratify or accede to the Paris Agreement and total global GHG percentage were achieved on October 5, 2016 and the Paris Agreement entered into force on November 4, 2016.  On June 1, 2017, President Trump announced that the U.S. would withdraw from the Paris Agreement. As a result of the President’s notice to the United Nations, the U.S. officially withdrew from the Paris Agreement on November 4, 2020. On January 20, 2021, President Biden signed an instrument that will allow the United States to rejoin the Paris Agreement on Climate Change. The instrument was deposited with the United Nations on January 21, 2021, and the United States officially became a party to the Agreement on February 19, 2021.

PNM has calculated GHG reductions that would result from scenarios that assume PNM’s scheduled retirement of its share of the SJGS in 2022 and would exit from Four Corners in either 2024 or 2031 and PNM has set a goal to have a 100% emissions-free generating portfolio by 2040. While the Company has not conducted an independent 2 Degree Scenario analysis, our commitment to becoming 100% emissions-free by 2040 produces a carbon emissions reduction pathway that tracks within the ranges of climate scenario pathways that are consistent with limiting the global warming average to less than 2 degrees Celsius. In addition, as an investor-owned utility operating in the state of New Mexico, PNM is required to comply with the recently enacted ETA, which requires utilities’ generating portfolio be 100% carbon-free by 2045. The requirements of the ETA and the Company’s goal compare favorably to the U.S. INDC of 50% to 52% carbon emissions reduction by 2030 and the Biden Administration's goal of net-zero carbon emissions economy-wide by 2050. On April 1, 2020, the NMPRC approved PNM’s application to retire its share of SJGS in 2022. PNM filed for abandonment of Four Corners on January 8, 2021. See Note 12.

PNM will continue to monitor the United States’ re-entry into the Paris Agreement and other parties’ involvement in these types of international accords, but the potential impact that such accords may have on the Company cannot be determined at this time.

Assessment of Legislative/Regulatory Impacts

The Company has assessed, and continues to assess, the impacts of climate change legislation and regulation on its business.  This assessment is ongoing and future changes arising out of the legislative or regulatory process could impact the assessment significantly.  PNM’s assessment includes assumptions regarding specific GHG limits; the timing of implementation of these limits; the possibility of a market-based trading program, including the associated costs and the availability of emission credits or allowances; the development of emission reduction and/or renewable energy technologies; and provisions for cost containment. Moreover, the assessment assumes various market reactions such as the price of coal and gas and regional plant economics.  These assumptions are, at best, preliminary and speculative. However, based upon these assumptions, the enactment of climate change legislation or regulation could, among other things, result in significant compliance costs, including large capital expenditures by PNM, and could jeopardize the economic viability of certain generating facilities. See Notes 11 and 12.  While PNM currently expects the retirement of SJGS in 2022 will provide savings to customers, the ultimate consequences of climate change and environmental regulation could lead to increased costs to customers and affect results of operations, cash flows, and financial condition if the incurred costs are not fully recovered through regulated rates. Higher rates could also contribute to reduced usage of electricity.  PNM’s assessment process is evolving and is too speculative at this time for a meaningful prediction of the long-term financial impact.

Transmission Issues

At any given time, FERC has various notices of inquiry and rulemaking dockets related to transmission issues pending. Such actions may lead to changes in FERC administrative rules or ratemaking policy but have no time frame in which action must be taken or a docket closed with no further action. Further, such notices and rulemaking dockets do not apply strictly to PNM but will have industry-wide effects in that they will apply to all FERC-regulated entities. PNM monitors and often submits comments taking a position in such notices and rulemaking dockets or may join in larger group responses. PNM often cannot determine the full impact of a proposed rule and policy change until the final determination is made by FERC and PNM is unable to predict the outcome of these matters.

Financial Reform Legislation

The Dodd-Frank Wall Street Reform and Consumer Protection Act (“Dodd-Frank Reform Act”), enacted in July 2010, includes provisions that will require certain over-the-counter derivatives, or swaps, to be centrally cleared and executed through an exchange or other approved trading facility. It also includes provisions related to swap transaction reporting and record keeping and may impose margin requirements on swaps that are not centrally cleared. The U.S. Commodity Futures Trading Commission (“CFTC”) has published final rules defining several key terms related to the act and has set compliance dates for various types of market participants. The Dodd-Frank Reform Act provides exemptions from certain requirements, including an exception to the mandatory clearing and swap facility execution requirements for commercial end-users that use swaps to hedge or mitigate commercial risk.  PNM has elected the end-user exception to the mandatory clearing requirement. PNM expects to be in compliance with the Dodd-Frank Reform Act and related rules within the time frames required by the CFTC. However, as a result of implementing and complying with the Dodd-Frank Reform Act and related rules, PNM’s swap activities

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could be subject to increased costs, including from higher margin requirements. At this time, PNM cannot predict the ultimate impact the Dodd-Frank Reform Act may have on PNM’s financial condition, results of operations, cash flows, or liquidity.

Other Matters

See Notes 11 and 12 herein and Notes 16 and 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K for a discussion of commitments and contingencies and rate and regulatory matters. See Note 1 for a discussion of accounting pronouncements that have been issued but are not yet effective and have not been adopted by the Company.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

The preparation of financial statements in accordance with GAAP requires Company management to select and apply accounting policies that best provide the framework to report the results of operations and financial position for PNMR, PNM, and TNMP. The selection and application of those policies requires management to make difficult, subjective, and/or complex judgments concerning reported amounts of revenue and expenses during the reporting period and the reported amounts of assets and liabilities at the date of the financial statements. As a result, there exists the likelihood that materially different amounts would be reported under different conditions or using different assumptions.

As of September 30, 2021, there have been no significant changes with regard to the critical accounting policies disclosed in PNMR’s, PNM’s, and TNMP’s 2020 Annual Reports on Forms 10-K. The policies disclosed included regulatory accounting, impairments, decommissioning and reclamation costs, pension and other postretirement benefits, accounting for contingencies, and income taxes.

MD&A FOR PNM

RESULTS OF OPERATIONS

PNM operates in only one reportable segment, as presented above in Results of Operations for PNMR.

MD&A FOR TNMP

RESULTS OF OPERATIONS

TNMP operates in only one reportable segment, as presented above in Results of Operations for PNMR.

DISCLOSURE REGARDING FORWARD LOOKING STATEMENTS

Statements made in this filing that relate to future events or PNMR’s, PNM’s, or TNMP’s expectations, projections, estimates, intentions, goals, targets, and strategies are made pursuant to the Private Securities Litigation Reform Act of 1995. Readers are cautioned that all forward-looking statements are based upon current expectations and estimates. PNMR, PNM, and TNMP assume no obligation to update this information.

Because actual results may differ materially from those expressed or implied by these forward-looking statements, PNMR, PNM, and TNMP caution readers not to place undue reliance on these statements. PNMR’s, PNM’s, and TNMP’s business, financial condition, cash flows, and operating results are influenced by many factors, which are often beyond their control, that can cause actual results to differ from those expressed or implied by the forward-looking statements. These factors include:

•The expected timing and likelihood of completion of the pending Merger, including the timing, receipt and terms and conditions of any required governmental and regulatory approvals of the pending Merger that could reduce anticipated benefits or cause the parties to abandon the transaction

•The occurrence of any event, change or other circumstances that could give rise to the termination of the Merger Agreement

•The risk that the parties may not be able to satisfy the conditions to the proposed Merger in a timely manner or at all

•The risk that the proposed Merger could have an adverse effect on the ability of PNMR to retain and hire key personnel and maintain relationships with its customers and suppliers, and on its operating results and businesses generally

•The ability of PNM and TNMP to recover costs and earn allowed returns in regulated jurisdictions, including the prudence of PNM’s decision to continue participation in Four Corners and recovery of PNM’s investments and other costs associated with that plant, and any actions resulting from the pending appeal of the NMPRC's approval of PNM's request to issue Securitized Bonds in PNM’s SJGS Abandonment Application (collectively, the “Regulatory Proceedings”) and the impact on service levels for PNM customers if the ultimate outcomes do not provide for the recovery of costs and operating and capital expenditures, as well as other impacts of federal or state regulatory and judicial actions

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•The ability of the Company to successfully forecast and manage its operating and capital expenditures, including aligning expenditures with the revenue levels resulting from the ultimate outcomes of the Regulatory Proceedings, or resulting from potential mid-term or long-term impacts related to COVID-19, and supporting forecasts utilized in FTY rate proceedings

•Uncertainty relating to PNM's recent decision to return the currently leased generating capacity in PVNGS Units 1 and 2 at the expiration of their lease terms in 2023 and 2024, including future regulatory outcomes relating to the ratemaking treatment and replacement resources for the leased assets and the NRC’s actions related to transfer of ownership

•Uncertainty surrounding the status of PNM’s participation in jointly-owned generation projects, including the 2022 scheduled expiration of the operational and fuel supply agreements for SJGS, the proposed exit of Four Corners in 2024, regulatory recovery of undepreciated investments and other costs in the event the NMPRC orders generating facilities be retired, and the impacts of the ETA

•Uncertainty regarding the requirements and related costs of decommissioning power plants and reclamation of coal mines supplying certain power plants, as well as the ability to recover those costs from customers, including the potential impacts of the ultimate outcomes of the Regulatory Proceedings

•The impacts on the electricity usage of customers and consumers due to performance of state, regional, and national economies, energy efficiency measures, weather, seasonality, alternative sources of power, advances in technology, the impacts of COVID-19 on customer usage, and other changes in supply and demand

•The Company’s ability to access the financial markets in order to provide financing to repay or refinance debt as it comes due, as well as for ongoing operations and construction expenditures, including disruptions in the capital or credit markets, actions by ratings agencies, and fluctuations in interest rates, including any negative impacts that could result from the ultimate outcomes of the Regulatory Proceedings, from the economic impacts of COVID-19 or from the entry into the Merger Agreement

•The risks associated with completion of generation, transmission, distribution, and other projects, including uncertainty related to regulatory approvals and cost recovery, and the ability of counterparties to meet their obligations under certain arrangements (including approved PPAs related to replacement resources for facilities to be retired), and supply chain or other outside support services that may be disrupted by the impacts of COVID-19

•The potential unavailability of cash from PNMR’s subsidiaries due to regulatory, statutory, or contractual restrictions or subsidiary earnings or cash flows

•The performance of generating units, transmission systems, and distribution systems, which could be negatively affected by operational issues, fuel quality and supply issues, unplanned outages, extreme weather conditions, wildfires, terrorism, cybersecurity breaches, and other catastrophic events, including the impacts of COVID-19, as well as the costs the Company may incur to repair its facilities and/or the liabilities the Company may incur to third parties in connection with such issues

•State and federal regulation or legislation relating to environmental matters and renewable energy requirements, the resultant costs of compliance, and other impacts on the operations and economic viability of PNM’s generating plants

•State and federal regulatory, legislative, executive, and judicial decisions and actions on ratemaking, and taxes, including guidance related to the Tax Act, and other matters

•Risks related to climate change, including potential financial risks resulting from climate change litigation and legislative and regulatory efforts to limit GHG, including the impacts of the ETA

•Employee workforce factors, including cost control efforts and issues arising out of collective bargaining agreements and labor negotiations with union employees

•Variability of prices and volatility and liquidity in the wholesale power and natural gas markets

•Changes in price and availability of fuel and water supplies, including the ability of the mines supplying coal to PNM’s coal-fired generating units and the companies involved in supplying nuclear fuel to provide adequate quantities of fuel

•Regulatory, financial, and operational risks inherent in the operation of nuclear facilities, including spent fuel disposal uncertainties

•The impacts of decreases in the values of marketable securities maintained in trusts to provide for decommissioning, reclamation, pension benefits, and other postretirement benefits, including potential increased volatility resulting from international developments and the impacts of COVID-19, as well as PNM's ability to recover future decommissioning and reclamation costs from customers

•Uncertainty surrounding counterparty performance and credit risk, including the ability of counterparties to supply fuel and perform reclamation activities and impacts to financial support provided to facilitate the coal supply at SJGS

•The effectiveness of risk management regarding commodity transactions and counterparty risk

•The outcome of legal proceedings, including the extent of insurance coverage

•Changes in applicable accounting principles or policies

Any material changes to risk factors occurring after the filing of PNMR’s, PNM’s, and TNMP’s 2020 Annual Reports on Form 10-K are disclosed in Item 1A, Risk Factors, in Part II of this Form 10-Q.

For information about the risks associated with the use of derivative financial instruments, see Item 3. “Quantitative and Qualitative Disclosures About Market Risk.”

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SECURITIES ACT DISCLAIMER

Certain securities described or cross-referenced in this report have not been registered under the Securities Act of 1933, as amended, or any state securities laws and may not be reoffered or sold in the United States absent registration or an applicable exemption from the registration requirements of the Securities Act of 1933 and applicable state securities laws. This Form 10-Q does not constitute an offer to sell or the solicitation of an offer to buy any securities.

WEBSITES

The PNMR website, www.pnmresources.com, is an important source of Company information. New or updated information for public access is routinely posted.  PNMR encourages analysts, investors, and other interested parties to register on the website to automatically receive Company information by e-mail. This information includes news releases, notices of webcasts, and filings with the SEC. Participants will not receive information that was not requested and can unsubscribe at any time.

Our corporate internet addresses are:

•PNMR: www.pnmresources.com

•PNM: www.pnm.com

•TNMP: www.tnmp.com

PNMR’s corporate website (www.pnmresources.com) includes a dedicated section providing key environmental and other sustainability information related to PNM’s and TNMP’s operations and other information that collectively demonstrates the Company’s commitment to ESG principles. This information highlights plans for PNM to be coal-free by 2024 (subject to regulatory approval) and to have an emissions-free generating portfolio by 2040.

The contents of these websites are not a part of this Form 10-Q. The SEC filings of PNMR, PNM, and TNMP, including annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act, are accessible free of charge on the PNMR website as soon as reasonably practicable after they are filed with, or furnished to, the SEC. Reports filed with the SEC are available on its website, www.sec.gov. These reports are also available in print upon request from PNMR free of charge.

Also available on the Company’s website at https://www.pnmresources.com/esg-commitment/governance.aspx and in print upon request from any shareholder are PNMR’s:

•Corporate Governance Principles

•Code of Ethics (Do the Right Thing – Principles of Business Conduct)

•Charters of the Audit and Ethics Committee, Nominating and Governance Committee, Compensation and Human Resources Committee, and Finance Committee

•Restated Articles of Incorporation and Bylaws

The Company will post amendments to or waivers from its code of ethics (to the extent applicable to the Company’s executive officers and directors) on its website.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The Company manages the scope of its various forms of market risk through a comprehensive set of policies and procedures with oversight by senior level management through the Risk Management Committee (“RMC”). The Board’s Finance Committee sets the risk limit parameters. The RMC has oversight over the risk control organization. The RMC is assigned responsibility for establishing and enforcing the policies, procedures, and limits and evaluating the risks inherent in proposed transactions on an enterprise-wide basis. The RMC’s responsibilities include:

•Establishing policies regarding risk exposure levels and activities in each of the business segments

•Approving the types of derivatives entered into for hedging

•Reviewing and approving hedging risk activities

•Establishing policies regarding counterparty exposure and limits

•Authorizing and delegating transaction limits

•Reviewing and approving controls and procedures for derivative activities

•Reviewing and approving models and assumptions used to calculate mark-to-market and market risk exposure

•Proposing risk limits to the Board’s Finance Committee for its approval

•Reporting to the Board’s Audit and Finance Committees on these activities

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To the extent an open position exists, fluctuating commodity prices, interest rates, equity prices, and economic conditions can impact financial results and financial position, either favorably or unfavorably. As a result, the Company cannot predict with certainty the impact that its risk management decisions may have on its businesses, operating results, or financial position.

Commodity Risk

Information concerning accounting for derivatives and the risks associated with commodity contracts is set forth in Note 7, including a summary of the fair values of mark-to-market energy related derivative contracts included in the Condensed Consolidated Balance Sheets. During the nine months ended September 30, 2021 and the year ended December 31, 2020, the Company had no commodity derivative instruments designated as cash flow hedging instruments.

Commodity contracts that meet the definition of a derivative are recorded at fair value on the Condensed Consolidated Balance Sheets. In the nine months ended September 30, 2021 and 2020, the effects of mark-to-market commodity derivative instruments had no impact to PNM's net earnings and $1.9 million and zero of fair value losses have been recorded as a regulatory asset. All of the fair values as of September 30, 2021 were determined based on prices provided by external sources other than actively quoted market prices. The net mark-to-market amounts will settle by 2022.

PNM is exposed to changes in the market prices of electricity and natural gas for the positions in its wholesale portfolio not covered by the FPPAC. The Company manages risks associated with these market fluctuations by utilizing various commodity instruments that may qualify as derivatives, including futures, forwards, options, and swaps. PNM uses such instruments to hedge its exposure to changes in the market prices of electricity and natural gas. PNM also uses such instruments under an NMPRC approved hedging plan to manage fuel and purchased power costs related to customers covered by its FPPAC.

Unusually cold weather in February 2021 resulted in higher than expected natural gas and purchased power costs. PNM mitigated the impacts from the cold weather by securing gas supplies in advance, engaging in market purchases when lower prices were available, and adjusting plant operation of its gas units to minimize reliance on higher-priced gas supplies. PNM estimates the impact of the cold weather conditions in the first quarter of 2021 resulted in approximately $20 million of additional natural gas costs and approximately $8 million in additional purchased power costs. These fuel increases are being passed through to customers under the FPPAC over the remainder of 2021.

Credit Risk

The Company is exposed to credit risk from its retail and wholesale customers, as well as the counterparties to derivative instruments. The Company conducts counterparty risk analysis across business segments and uses a credit management process to assess the financial conditions of counterparties. The following table provides information related to credit exposure by the credit worthiness (credit rating) and concentration of credit risk for wholesale counterparties, all of which will mature in less than two years.

Schedule of Credit Risk Exposure
September 30, 2021
Rating (1)	Credit Risk Exposure(2)		Number of Counter-parties >10%	Net Exposure of Counter-parties >10%
	(Dollars in thousands)
External ratings:
Investment grade	$	6,443	1	$	5,741
Non-investment grade	—		—	—
Split ratings	—		—	—
Internal ratings:
Investment grade	1,069		—	—
Non-investment grade	—		—	—
Total	$	7,512		$	5,741

(1)The rating “Investment Grade” is for counterparties, or a guarantor, with a minimum S&P rating of BBB- or Moody’s rating of Baa3. The category “Internal Ratings – Investment Grade” includes those counterparties that are internally rated as investment grade in accordance with the guidelines established in the Company’s credit policy.

(2)The Credit Risk Exposure is the gross credit exposure, including long-term contracts (other than the Tri-State hazard sharing agreement), forward sales, and short-term sales. The gross exposure captures the amounts from receivables/payables for realized transactions, delivered and unbilled revenues, and mark-to-market gains/losses. Gross exposures can be offset according to legally enforceable netting arrangements but are not reduced by posted credit collateral. At September 30, 2021, PNMR held $0.9 million of cash collateral to offset its credit exposure.

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Net credit risk for the Company’s largest counterparty as of September 30, 2021 was $5.7 million.

Other investments have no significant counterparty credit risk.

Interest Rate Risk

The majority of the Company’s long-term debt is fixed-rate debt and does not expose earnings to a major risk of loss due to adverse changes in market interest rates. However, the fair value of PNMR’s consolidated long-term debt instruments would increase by 2.7%, or $100.6 million if interest rates were to decline by 50 basis points from their levels at September 30, 2021. In general, an increase in fair value would impact earnings and cash flows to the extent not recoverable in rates if all or a portion of debt instruments were acquired in the open market prior to their maturity. The Company is exposed to interest rate risk to the extent of future increases in variable interest rates. Variable interest rates are based on LIBOR but contain provisions which allow for the replacement of LIBOR with other widely accepted interest rates. The Company expects that it will be able to extend or replace these credit facilities under similar terms and conditions prior to their expirations.

At October 22, 2021, variable rate debt balances and weighted average interest rates were as follows:

Variable Rate Debt	Weighted Average Interest Rate		Balance Outstanding		Capacity
			(In thousands)
Short-term Debt:
PNMR Revolving Credit Facility	1.59	%	$	10,600	$	300,000
PNM Revolving Credit Facility	—		—		400,000
PNM 2017 New Mexico Credit Facility	—		—		40,000
TNMP Revolving Credit Facility	—		—		75,000
			$	10,600	$	815,000
Long-term Debt:
PNMR 2021 Delayed-Draw Term Loan	0.94	%	$	850,000
PNM 2021 Term Loan	0.91		75,000
			$	925,000

The investments held by PNM in trusts for decommissioning and reclamation had an estimated fair value of $455.4 million at September 30, 2021, of which 58.4% were fixed-rate debt securities that subject PNM to risk of loss of fair value with increases in market interest rates. If interest rates were to increase by 50 basis points from their levels at September 30, 2021, the decrease in the fair value of the fixed-rate securities would be 2.2%, or $5.9 million.

PNM does not directly recover or return through rates any losses or gains on the securities, including equity investments discussed below, in the trusts for decommissioning and reclamation. However, the overall performance of these trusts does enter into the periodic determinations of expense and funding levels, which are factored into the rate making process to the extent applicable to regulated operations. The NMPRC ruled in the NM 2015 Rate Case that PNM would not be able to include future contributions made by PNM for decommissioning of PVNGS to the extent applicable to certain capacity purchased and leased by PNM in rates charged to retail customers. The NM Supreme Court ruled that the NMPRC’s decision to disallow recovery of such future contributions for decommissioning denied PNM due process and remanded the matter back to the NMPRC for further proceedings. See Note 12. PNM is at risk for shortfalls in funding of obligations due to investment losses, including those from the equity market risks discussed below, to the extent not ultimately recovered through rates charged to customers.

Equity Market Risk

The investments held by PNM in trusts for decommissioning and reclamation include certain equity securities at September 30, 2021. These equity securities expose PNM to losses in fair value should the market values of the underlying securities decline. Equity securities comprised 39.8% of the securities held by the trusts as of September 30, 2021. A hypothetical 10% decrease in equity prices would reduce the fair values of these funds by $18.1 million.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of disclosure controls and procedures

As of the end of the period covered by this quarterly report, each of PNMR, PNM, and TNMP conducted an evaluation, under the supervision and with the participation of its management, including its Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934). Based upon this evaluation, the Chief Executive Officer and the Chief Financial Officer of each of PNMR, PNM, and TNMP concluded that the disclosure controls and procedures are effective.

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Changes in internal controls over financial reporting

There have been no changes in each of PNMR’s, PNM’s, and TNMP’s internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934) during the quarter ended September 30, 2021 that have materially affected, or are reasonably likely to materially affect, each of PNMR’s, PNM’s, and TNMP’s internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

See Notes 11 and 12 for information related to the following matters, for PNMR, PNM, and TNMP, incorporated in this item by reference.

Note 11

•Navajo Nation Environmental Issues

•Cooling Water Intake Structures

•Santa Fe Generating Station

•Continuous Highwall Mining Royalty Rate

•PVNGS Water Supply Litigation

•San Juan River Adjudication

•Navajo Nations Allottee Matters

•Texas Winter Storm

Note 12

•PNM – Renewable Portfolio Standard

•PNM – Energy Efficiency and Load Management

•PNM – Integrated Resource Plans

•PNM – 2020 Decoupling

•PNM – SJGS Abandonment Application

•PNM – Four Corners Abandonment Application

•PNM – PVNGS Leased Interest Abandonment Application

•PNM – COVID-19 Regulatory Matters

•TNMP – Periodic Distribution Rate Adjustment

ITEM 1A. RISK FACTORS

As of the date of this report, there have been no material changes with regard to the Risk Factors disclosed in PNMR's, PNM's, and TNMP's Annual Reports on Form 10-K for the year ended December 31, 2020.

ITEM 5. OTHER INFORMATION

None

ITEM 6. EXHIBITS

3.1	PNMR	Articles of Incorporation of PNMR, as amended to date (incorporated by reference to Exhibit 3.1 to PNMR’s Current Report on Form 8-K filed November 21, 2008)
3.2	PNM	Restated Articles of Incorporation of PNM, as amended through May 31, 2002 (incorporated by reference to Exhibit 3.1.1 to PNM’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2002)
3.3	TNMP	Articles of Incorporation of TNMP, as amended through July 7, 2005 (incorporated by reference to Exhibit 3.1.2 to TNMP’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005)
3.4	PNMR	Bylaws of PNMR, with all amendments to and including October 24, 2017 (incorporated by reference to Exhibit 3.1 to PNMR’s Current Report on Form 8-K filed October 25, 2017)
3.5	PNM	Bylaws of PNM, with all amendments to and including May 31, 2002 (incorporated by reference to Exhibit 3.1.2 to PNM’s Report on Form 10-Q for the fiscal quarter ended June 30, 2002)
3.6	TNMP	Bylaws of TNMP, with all amendments to and including June 18, 2013 (incorporated by reference to Exhibit 3.6 to TNMP’s Current Report on Form 8-K filed June 20, 2013)

121

4.1	TNMP	Fourteenth Supplemental Indenture, dated as of August 16, 2021, between Texas-New Mexico Power Company and U.S. Bank National Association, as Trustee (incorporated by reference to Exhibit 4.1 to TNMP's Current Report on Form 8-K filed August 16, 2021)
10.1	PNMR	Ninth Amendment to Credit Agreement, dated as of September 15, 2021, among PNMR, the lenders party thereto, and Wells Fargo Bank, National Association, as administrative agent (PNMR Revolving Credit Facility)
10.2	PNM	Note Purchase Agreement, dated July 14, 2021, between Public Service Company of New Mexico and the purchasers named therein (incorporated by reference to Exhibit 10.1 to PNM's Current Report on Form 8-K filed July 14, 2021)
10.3	PNM	Note Purchase Agreement, dated September 23, 2021, between Public Service Company of New Mexico and the purchasers named therein (incorporated by reference to Exhibit 10.1 to PNM's Current Report on Form 8-K filed September 23, 2021)
10.4	TNMP	Bond Purchase Agreement, dated July 14, 2021, between Texas-New Mexico Power Company and the purchasers named therein (incorporated by reference to Exhibit 10.2 to TNMP's Current Report on Form 8-K filed July 14, 2021)
10.5	TNMP	Third Amendment to Third Amended and Restated Credit Agreement, dated as of September 15, 2021, among TNMP identified therein and KeyBank, National Association, as administrative agent (TNMP Revolving Credit Facility)
31.1	PNMR	Chief Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2	PNMR	Chief Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.3	PNM	Chief Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.4	PNM	Chief Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.5	TNMP	Chief Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.6	TNMP	Chief Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1	PNMR	Chief Executive Officer and Chief Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2	PNM	Chief Executive Officer and Chief Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.3	TNMP	Chief Executive Officer and Chief Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS	PNMR, PNM, and TNMP	XBRL Instance Document - The instance document does not appear in the interactive data file because XBRL tags are embedded within the Inline XBRL document
101.SCH	PNMR, PNM, and TNMP	Inline XBRL Taxonomy Extension Schema Document
101.CAL	PNMR, PNM, and TNMP	Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF	PNMR, PNM, and TNMP	Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB	PNMR, PNM, and TNMP	Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE	PNMR, PNM, and TNMP	Inline XBRL Taxonomy Extension Presentation Linkbase Document
104	PNMR, PNM, and TNMP	Cover Page Inline XBRL File (included in Exhibits 101)

122

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.

		PNM RESOURCES, INC. PUBLIC SERVICE COMPANY OF NEW MEXICO TEXAS-NEW MEXICO POWER COMPANY
		(Registrants)
Date:	October 28, 2021	/s/ Henry E. Monroy
		Henry E. Monroy
		Vice President and Corporate Controller
		(Officer duly authorized to sign this report)

123

EX-10.1

Exhibit 10.1

EXECUTION VERSION

NINTH AMENDMENT TO CREDIT AGREEMENT

THIS NINTH AMENDMENT TO CREDIT AGREEMENT (this “Amendment”) is effective as of September 15, 2021, among PNM RESOURCES, INC., a New Mexico corporation (the “Borrower”), the Lenders party hereto and WELLS FARGO BANK, NATIONAL ASSOCIATION, as Administrative Agent for the Lenders (in such capacity, the “Administrative Agent”). Capitalized terms used herein and not otherwise defined shall have the meanings assigned thereto in the Credit Agreement (as defined below).

R E C I T A L S

WHEREAS, the Borrower, the Lenders party thereto and the Administrative Agent are parties to that certain Sixth Amendment to and Restatement of Credit Agreement, dated as of July 30, 2018 (as amended by a Seventh Amendment to Credit Agreement dated December 19, 2018 and an Eighth Amendment to Credit Agreement dated October 26, 2020 and as further amended or modified from time to time, the “Credit Agreement”);

WHEREAS, the Borrower has requested certain modifications to the Credit Agreement as described below; and

WHEREAS, the Administrative Agent and the Lenders party hereto are willing to agree to such modifications and the other provisions contained herein, subject to the terms set forth herein as more fully set forth below.

NOW, THEREFORE, in consideration of the premises and the mutual covenants contained herein, and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto agree as follows:

A G R E E M E N T

1.    Amendments to Credit Agreement.

(a)    The following shall be added as a new definition in Section 1.1 of the Credit Agreement in alphabetical order:

“Avangrid Merger” has the meaning set forth in the definition of “Change of Control”.

(b)    The definition of “Change of Control” in Section 1.1 of the Credit Agreement is hereby amended and restated in its entirety to read as follows:

“Change of Control” means the occurrence of any of the following: (a) other than in connection with the Merger Agreement and the transactions contemplated thereby (the “Avangrid Merger”), any “person” or “group” (as such terms are used in Sections 13(d) and 14(d) of the Securities Exchange Act of 1934, but excluding any employee benefit plan of such person or its subsidiaries, and any person or entity acting in its capacity as trustee, agent or other fiduciary or administrator of any such plan) becomes the “beneficial owner” (as defined in Rules 13d-3 and 13d-5 under the Securities Exchange Act of 1934, except that a person or group shall be deemed to have “beneficial ownership” of all Capital Stock that such person or group has the right to acquire (other than pursuant to the Merger Agreement) (such right, an “option right”), whether such right is exercisable immediately or only after the passage of time), directly or indirectly, of twenty-five percent (25%) of the Capital Stock of the Borrower entitled to vote for members of the

board of directors or equivalent governing body of the Borrower on a fully diluted basis (and taking into account all such securities that such person or group has the right to acquire pursuant to any option right); (b) other than in connection with the Avangrid Merger, during any period of twenty-four (24) consecutive months, a majority of the members of the board of directors or other equivalent governing body of the Borrower cease to be composed of individuals (i) who were members of that board or equivalent governing body on the first day of such period, (ii) whose election or nomination to that board or equivalent governing body was approved by individuals referred to in clause (i) above constituting at the time of such election or nomination at least a majority of that board or equivalent governing body or (iii) whose election or nomination to that board or other equivalent governing body was approved by individuals referred to in clauses (i) and (ii) above constituting at the time of such election or nomination at least a majority of that board or equivalent governing body; or (c) other than in connection with the Avangrid Merger, any Person or two or more Persons acting in concert shall have acquired by contract or otherwise, or shall have entered into a contract or arrangement that, upon consummation thereof, will result in its or their acquisition of the power to exercise, directly or indirectly, a controlling influence over the management or policies of Borrower, or control over the Voting Stock of the Borrower on a fully-diluted basis (and taking into account all such Voting Stock that such Person or group has the right to acquire pursuant to any option right) representing twenty-five percent (25%) or more of the combined voting power of such Voting Stock.

(c)Section 8.2 of the Credit Agreement is hereby amended to insert immediately after the phrase “merge with or into any other Person” now appearing in clause (a) thereof, the following: “(other than in connection with the Merger Agreement)”.

2.    Effectiveness.

This Amendment shall be effective as of the date set forth above upon satisfaction of the following conditions precedent:

(a)    Receipt by the Administrative Agent of copies of this Amendment duly executed by the Borrower and the Required Lenders.

(b)    The Borrower shall have paid to the Administrative Agent all fees and expenses due and payable to the Administrative Agent and the Lenders on the date hereof.

3.    Ratification of Credit Agreement. The term “Credit Agreement” as used in each of the Credit Documents shall hereafter mean the Credit Agreement as amended and modified by this Amendment. Except as herein specifically agreed, the Credit Agreement, as amended by this Amendment, is hereby ratified and confirmed and shall remain in full force and effect according to its terms. Each party hereto acknowledges and consents to the modifications set forth herein and agrees that, other than as explicitly set forth in Section 1 above, this Amendment does not impair, reduce or limit any of its obligations under the Credit Documents (including, without limitation, the indemnity obligations set forth therein) and that, after the date hereof, this Amendment shall constitute a Credit Document. The execution, delivery and effectiveness of this Amendment shall not, except as expressly provided herein, operate as a waiver of any right, power or remedy of any Lender or the Administrative Agent under any of the Credit Documents or constitute a waiver of any provision of any of the Credit Documents.

4.    Authority/Enforceability. The Borrower represents and warrants as follows:

(a)    It has taken all necessary action to authorize the execution, delivery and performance of this Amendment.

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(b)    This Amendment has been duly executed and delivered by the Borrower and constitutes the Borrower’s legal, valid and binding obligation, enforceable in accordance with its terms, except as such enforceability may be subject to (i) bankruptcy, insolvency, reorganization, fraudulent conveyance or transfer, moratorium or similar laws affecting creditors' rights generally and (ii) general principles of equity (regardless of whether such enforceability is considered in a proceeding at law or in equity).

(c)    No consent, approval, authorization or order of, or filing, registration or qualification with, any court or governmental authority or third party is required in connection with the execution, delivery or performance by the Borrower of this Amendment, or, if required, any such consent, approval, authorization, order, filing, registration or qualification has been previously obtained or made.

5.    Representations and Warranties. The Borrower represents and warrants to the Lenders that (a) the representations and warranties of the Borrower set forth in Section 6 of the Credit Agreement are true and correct in all material respects (except to the extent that any such representation and warranty that is qualified by materiality, Material Adverse Effect or Material Adverse Change shall be true and correct in all respects) as of the date hereof, unless they specifically refer to an earlier date, except that all references in Section 6.7 of the Credit Agreement to December 31, 2017 shall be changed to December 31, 2020 for purposes hereof, (b) no event has occurred and is continuing which constitutes a Default or an Event of Default, and (c) it has no claims, counterclaims, offsets, credits or defenses to its obligations under the Credit Documents, or to the extent it has any, they are hereby released in consideration of the Lenders party hereto entering into this Amendment.

6.    No Conflicts. The Borrower represents and warrants that the execution and delivery of this Amendment, the consummation of the transactions contemplated herein and in the Credit Agreement (before and after giving effect to this Amendment), and the performance of and compliance with the terms and provisions hereof by the Borrower will not (a) violate, contravene or conflict with any provision of its articles or certificate of incorporation, bylaws or other organizational or governing document, (b) violate, contravene or conflict with any law, rule, regulation (including, without limitation, Regulation U and Regulation X), order, writ, judgment, injunction, decree or permit applicable to the Borrower, (c) violate, contravene or conflict with contractual provisions of, or cause an event of default under, any indenture, loan agreement, mortgage, deed of trust, contract or other agreement or instrument to which the Borrower is a party or by which it or its properties may be bound, the violation of which would have or would reasonably be expected to have a Material Adverse Effect or (d) result in or require the creation of any Lien upon or with respect to the Borrower's properties.

7.    Counterparts/Telecopy. This Amendment may be executed by one or more of the parties hereto on any number of separate counterparts, including both paper and electronic counterparts, and all of said counterparts taken together shall be deemed to constitute one and the same instrument. Signatures delivered by facsimile or PDF shall have the same force and effect as manual signatures delivered in person. This Amendment may be executed using Electronic Signatures (including, without limitation, facsimile and .pdf) and shall be considered an original, and shall have the same legal effect, validity and enforceability as a paper record. For the avoidance of doubt, the authorization under this paragraph may include, without limitation, use or acceptance by the Administrative Agent of a manually signed paper hereof which has been converted into electronic form (such as scanned into PDF format), or an electronically signed communication converted into another format, for transmission, delivery and/or retention. For purposes hereof, “Electronic Signature” shall have the meaning assigned to it by 15 USC §7006, as it may be amended from time to time.

3

8.    GOVERNING LAW. THIS AMENDMENT AND THE RIGHTS AND OBLIGATIONS OF THE PARTIES HEREUNDER SHALL BE GOVERNED BY AND CONSTRUED AND INTERPRETED IN ACCORDANCE WITH THE LAWS OF THE STATE OF NEW YORK.

[remainder of page intentionally left blank]

4

Each of the parties hereto has caused a counterpart of this Amendment to be duly executed and delivered as of the date first above written.

BORROWER:

PNM RESOURCES, INC.,

a New Mexico corporation

By:    /s/ Elisabeth A. Eden                    

Name: Elisabeth A. Eden

Title: Vice President and Treasurer

ADMINISTRATIVE AGENT:

WELLS FARGO BANK, NATIONAL ASSOCIATION,

as Administrative Agent, as a Lender and as an L/C Issuer

By:    /s/ Gregory R. Gredvig            

Name:    Gregory R. Gredvig            

Title:    Director                

LENDERS:                

MUFG UNION BANK, N.A.,

as a Lender and an L/C Issuer

By:    /s/ Hazuki Watanabe            

Name:    Hazuki Watanabe            

Title:    Vice President                

CITIBANK, N.A.,

as a Lender

By:    /s/ Ashwani Khubani            

Name:    Ashwani Khubani            

Title:    Managing Director / Vice President    

JPMORGAN CHASE BANK, N.A.,

as a Lender

By:    /s/ Nancy R. Barwig            

Name:    Nancy R. Barwig            

Title:    Executive Director            

MORGAN STANLEY BANK, N.A.,

as a Lender

By:    /s/ Julie Hong                

Name:    Julie Hong                

Title:    Authorized Signatory            

ROYAL BANK OF CANADA,

as a Lender

By:    /s/ Mark W. Condon            

Name:    Mark W. Condon            

Title:    Authorized Signatory            

KEYBANK NATIONAL ASSOCIATION,

as a Lender

By:    /s/ Paul J. Pace                

Name:    Paul J. Pace                

Title:    Senior Vice President            

BANK OF AMERICA, N.A.,

as a Lender

By:    /s/ Scott Blackman            

Name:    Scott Blackman                

Title:    SVP                    

U.S. BANK, NATIONAL ASSOCIATION,

as a Lender

By:    /s/ Joe Horrigan                

Name:    Joe Horrigan                

Title:    Managing Director            

THE BANK OF NEW YORK MELLON,

as a Lender

By:    /s/ Molly H. Ross            

Name:    Molly H, Ross                

Title:    Vice President                

BOKF, NA d/b/a BANK OF ALBUQUERQUE,

as a Lender

By:    /s/ John Valentine            

Name:    John Valentine                

Title:    SVP                    

EX-10.5

Exhibit 10.5

EXECUTION VERSION

THIRD AMENDMENT TO THIRD AMENDED AND RESTATED CREDIT AGREEMENT

THIS THIRD AMENDMENT TO THIRD AMENDED AND RESTATED CREDIT AGREEMENT (this “Amendment”) is entered into as of September 15, 2021, among TEXAS-NEW MEXICO POWER COMPANY, a Texas corporation (the “Borrower”), the Lenders party hereto and KEYBANK, NATIONAL ASSOCIATION, as Administrative Agent for the Lenders (in such capacity, the “Administrative Agent”). Capitalized terms used herein and not otherwise defined shall have the meanings assigned thereto in the Credit Agreement (as defined below).

R E C I T A L S

WHEREAS, the Borrower, the Lenders party thereto and the Administrative Agent are parties to that certain Third Amended and Restated Credit Agreement, dated as of September 25, 2017 (as amended by a First Amendment to Third Amended and Restated Credit Agreement dated April 19, 2019 and a Second Amendment to Third Amended and Restated Credit Agreement dated October 26, 2020, and as further amended or modified from time to time, the “Credit Agreement”);

WHEREAS, the Borrower has requested certain modifications to the Credit Agreement as described below; and

WHEREAS, the Administrative Agent and the Lenders party hereto are willing to agree to such modifications and the other provisions contained herein, subject to the terms set forth herein as more fully set forth below.

NOW, THEREFORE, in consideration of the premises and the mutual covenants contained herein, and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto agree as follows:

A G R E E M E N T

1.    Amendments to Credit Agreement. Effective as of the date first written above and subject to the conditions set forth in Section 2 below, the Credit Agreement is hereby amended as follows:

(a)     The following shall be added as a new definition in Section 1.1 of the Credit Agreement in alphabetical order:

“Avangrid Merger” has the meaning set forth in the definition of “Change of Control”.

(b)    The definition of “Change of Control” in Section 1.1 of the Credit Agreement is hereby amended and restated in its entirety to read as follows:

“Change of Control” means the occurrence of any of the following: (a) other than in connection with the Merger Agreement and the transactions contemplated thereby (the “Avangrid Merger”), any “person” or “group” (as such terms are used in Sections 13(d) and 14(d) of the Securities Exchange Act of 1934, but excluding any employee benefit plan of such person or its subsidiaries, and any person or entity acting in its capacity as trustee, agent or other fiduciary or administrator of any such plan) becomes the “beneficial

owner” (as defined in Rules 13d-3 and 13d-5 under the Securities Exchange Act of 1934, except that a person or group shall be deemed to have “beneficial ownership” of all Capital Stock that such person or group has the right to acquire (other than pursuant to the Merger Agreement) (such right, an “option right”), whether such right is exercisable immediately or only after the passage of time), directly or indirectly, of twenty-five percent (25%) of the Capital Stock of the Parent entitled to vote for members of the board of directors or equivalent governing body of the Parent on a fully diluted basis (and taking into account all such securities that such person or group has the right to acquire pursuant to any option right); (b) other than in connection with the Avangrid Merger, during any period of twenty-four (24) consecutive months, a majority of the members of the board of directors or other equivalent governing body of the Parent cease to be composed of individuals (i) who were members of that board or equivalent governing body on the first day of such period, (ii) whose election or nomination to that board or equivalent governing body was approved by individuals referred to in clause (i) above constituting at the time of such election or nomination at least a majority of that board or equivalent governing body or (iii) whose election or nomination to that board or other equivalent governing body was approved by individuals referred to in clauses (i) and (ii) above constituting at the time of such election or nomination at least a majority of that board or equivalent governing body; (c) other than in connection with the Avangrid Merger, any Person or two or more Persons acting in concert shall have acquired by contract or otherwise, or shall have entered into a contract or arrangement that, upon consummation thereof, will result in its or their acquisition of the power to exercise, directly or indirectly, a controlling influence over the management or policies of Parent, or control over the Voting Stock of the Parent on a fully-diluted basis (and taking into account all such Voting Stock that such Person or group has the right to acquire pursuant to any option right) representing twenty-five percent (25%) or more of the combined voting power of such Voting Stock; or (d) the Parent shall cease to own, directly or indirectly, and free and clear of all Liens or other encumbrances (other than any Lien in favor of the lenders under any Material Credit Agreement securing Indebtedness thereunder), at least 100% of the outstanding Voting Stock of the Borrower on a fully diluted basis.

(c)    Section 8.2 of the Credit Agreement is hereby amended to insert immediately after the phrase “merge with or into any other Person” now appearing in clause (a) thereof, the following: “(other than in connection with the Merger Agreement)”.

2.    Effectiveness. This Amendment shall be effective on the date of receipt by the Administrative Agent of (i) copies of this Amendment duly executed by the Borrower, the Administrative Agent and the Required Lenders and (ii) the Administrative Agent’s and its affiliates’ fees and expenses (including fees and expenses of counsel for the Administrative Agent) in connection with this Amendment (such date, the “Effective Date”).

3.    Ratification of Credit Agreement. The term “Credit Agreement” as used in each of the Credit Documents shall hereafter mean the Credit Agreement as amended and modified by this Amendment and as amended and modified from time to time hereafter. Except as herein specifically agreed, the Credit Agreement, as amended by this Amendment, is hereby ratified and confirmed and shall remain in full force and effect according to its terms. Each party hereto acknowledges and consents to the modifications set forth herein and agrees that, other than as explicitly set forth in Section 1 above, this Amendment does not impair, reduce or limit any of its obligations under the Credit Documents (including, without limitation, the indemnity obligations set forth therein) and that, after the date hereof, this Amendment shall constitute a Credit Document. The execution, delivery and effectiveness of this Amendment shall not, except as expressly provided herein, operate as a waiver of any right, power or remedy of any Lender or the

Administrative Agent under any of the Credit Documents or constitute a waiver of any provision of any of the Credit Documents.

5.    Authority/Enforceability. The Borrower represents and warrants as follows:

(a)    It has taken all necessary action to authorize the execution, delivery and performance of this Amendment.

(b)    This Amendment has been duly executed and delivered by the Borrower and constitutes the Borrower’s legal, valid and binding obligation, enforceable in accordance with its terms, except as such enforceability may be subject to (i) bankruptcy, insolvency, reorganization, fraudulent conveyance or transfer, moratorium or similar laws affecting creditors’ rights generally and (ii) general principles of equity (regardless of whether such enforceability is considered in a proceeding at law or in equity).

(c)    No consent, approval, authorization or order of, or filing, registration or qualification with, any court or governmental authority or third party is required in connection with the execution, delivery or performance by the Borrower of this Amendment, or, if required, any such consent, approval, authorization, order, filing, registration or qualification has been previously obtained or made.

5.    Representations and Warranties. The Borrower represents and warrants to the Lenders that (a) the representations and warranties of the Borrower set forth in Section 6 of the Credit Agreement are true and correct in all material respects (except to the extent that any such representation and warranty that is qualified by materiality, Material Adverse Effect or Material Adverse Change shall be true and correct in all respects) as of the date hereof, unless they specifically refer to an earlier date, except that all references in Section 6.7 of the Credit Agreement to December 31, 2016 shall be changed to December 31, 2020 for purposes hereof, (b) after giving effect to this Amendment, no event has occurred and is continuing which constitutes a Default or an Event of Default, and (c) it has no claims, counterclaims, offsets, credits or defenses to its obligations under the Credit Documents, or to the extent it has any, they are hereby released in consideration of the Lenders party hereto entering into this Amendment.

6.    No Conflicts. The Borrower represents and warrants that the execution and delivery of this Amendment, the consummation of the transactions contemplated herein and in the Credit Agreement (before and after giving effect to this Amendment), and the performance of and compliance with the terms and provisions hereof by the Borrower will not (a) violate, contravene or conflict with any provision of its articles or certificate of incorporation, bylaws or other organizational or governing document, (b) violate, contravene or conflict with any law, rule, regulation (including, without limitation, Regulation U and Regulation X), order, writ, judgment, injunction, decree or permit applicable to the Borrower, (c) violate, contravene or conflict with contractual provisions of, or cause an event of default under, any indenture, loan agreement, mortgage, deed of trust, contract or other agreement or instrument to which the Borrower is a party or by which it or its properties may be bound, the violation of which would have or would be reasonably expected to have a Material Adverse Effect or (d) result in or require the creation of any Lien upon or with respect to the Borrower’s properties (except the Lien of the FMB Mortgage Documents in favor of the First Mortgage Bond Trustee).

7.    Counterparts/Telecopy. This Amendment may be executed by one or more of the parties hereto on any number of separate counterparts, including both paper and electronic counterparts, and all of said counterparts taken together shall be deemed to constitute one and the same instrument. Signatures delivered by facsimile or PDF shall have the same force and effect as manual signatures delivered in person. This Amendment may be executed using Electronic Signatures (including, without limitation, facsimile and .pdf) and shall be considered an original, and shall have the same legal effect, validity and enforceability

as a paper record. For the avoidance of doubt, the authorization under this paragraph may include, without limitation, use or acceptance by the Administrative Agent of a manually signed paper hereof which has been converted into electronic form (such as scanned into PDF format), or an electronically signed communication converted into another format, for transmission, delivery and/or retention. For purposes hereof, “Electronic Signature” shall have the meaning assigned to it by 15 USC §7006, as it may be amended from time to time.

8.    GOVERNING LAW. THIS AMENDMENT AND THE RIGHTS AND OBLIGATIONS OF THE PARTIES HEREUNDER SHALL BE GOVERNED BY AND CONSTRUED AND INTERPRETED IN ACCORDANCE WITH THE LAWS OF THE STATE OF NEW YORK.

[remainder of page intentionally left blank]

Each of the parties hereto has caused a counterpart of this Amendment to be duly executed and delivered as of the date first above written.

BORROWER:

TEXAS-NEW MEXICO POWER COMPANY,

a Texas corporation

By:    /s/ Elisabeth A. Eden            

Name:    Elisabeth A. Eden            

Title:    Vice President and Treasurer        

ADMINISTRATIVE AGENT:

KEYBANK, NATIONAL ASSOCIATION,

as Administrative Agent and as a Lender

By:    /s/ Paul J. Pace                

Name:    Paul J. Pace                

Title:    Senior Vice President            

LENDERS:                

JPMORGAN CHASE BANK, N.A.,

as a Lender

By:    /s/ Nancy R. Barwig            

Name:    Nancy R. Barwig            

Title:    Executive Director            

MUFG UNION BANK, N.A.,

as a Lender

By:    /s/ Hazuki Watanabe            

Name:    Hazuki Watanabe            

Title:    Vice President                

WELLS FARGO BANK, NATIONAL ASSOCIATION,

as a Lender

By:    /s/ Gregory R. Gredvig            

Name:    Gregory R. Gredvig            

Title:    Director                

EX-31.1

PNM Resources

414 Silver Ave. SW

Albuquerque, NM 87102-3289

EXHIBIT 31.1

CERTIFICATION

I, Patricia K. Collawn, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of PNM Resources, Inc.;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (each registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a)All significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	October 28, 2021	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			Chairman, President and Chief Executive Officer
			PNM Resources, Inc.

EX-31.2

PNM Resources

414 Silver Ave. SW

Albuquerque, NM 87102-3289

EXHIBIT 31.2

CERTIFICATION

I, Joseph D. Tarry, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of PNM Resources, Inc.;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (each registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a)All significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	October 28, 2021	By:	/s/ Joseph D. Tarry
			Joseph D. Tarry
			Senior Vice President and
			Chief Financial Officer
			PNM Resources, Inc.

EX-31.3

Public Service Company of New Mexico

414 Silver Ave. SW

Albuquerque, NM 87102-3289

EXHIBIT 31.3

CERTIFICATION

I, Patricia K. Collawn, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of Public Service Company of New Mexico;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (each registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a)All significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	October 28, 2021	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			President and Chief Executive Officer
			Public Service Company of New Mexico

EX-31.4

Public Service Company of New Mexico

414 Silver Ave. SW

Albuquerque, NM 87102-3289

EXHIBIT 31.4

CERTIFICATION

I, Joseph D. Tarry, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of Public Service Company of New Mexico;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (each registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a)All significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	October 28, 2021	By:	/s/ Joseph D. Tarry
			Joseph D. Tarry
			Senior Vice President and
			Chief Financial Officer
			Public Service Company of New Mexico

EX-31.5

Texas-New Mexico Power Company

577 N. Garden Ridge Blvd.

Lewisville, Texas 75067

EXHIBIT 31.5

CERTIFICATION

I, Patricia K. Collawn, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of Texas-New Mexico Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (each registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a)All significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	October 28, 2021	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			Chief Executive Officer
			Texas-New Mexico Power Company

EX-31.6

Texas-New Mexico Power Company

577 N. Garden Ridge Blvd.

Lewisville, Texas 75067

EXHIBIT 31.6

CERTIFICATION

I, Joseph D. Tarry, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of Texas-New Mexico Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (each registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a)All significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	October 28, 2021	By:	/s/ Joseph D. Tarry
			Joseph D. Tarry
			Senior Vice President and
			Chief Financial Officer
			Texas-New Mexico Power Company

EX-32.1

PNM Resources

414 Silver Ave. SW

Albuquerque, NM 87102-3289

www.pnmresources.com

EXHIBIT 32.1

CERTIFICATION PURSUANT TO 18 U.S.C. § 1350, AS ADOPTED PURSUANT TO § 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q for the period ended September 30, 2021, for PNM Resources, Inc. (“Company”), as filed with the Securities and Exchange Commission on October 28, 2021 (“Report”), each of the undersigned officers of the Company certifies, pursuant to 18 U.S.C. §1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1)the Report fully complies with the requirements of § 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2)the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	October 28, 2021	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			Chairman, President and Chief Executive Officer
			PNM Resources, Inc.
		By:	/s/ Joseph D. Tarry
			Joseph D. Tarry
			Senior Vice President and
			Chief Financial Officer
			PNM Resources, Inc.

EX-32.2

Public Service Company of New Mexico

414 Silver Ave. SW

Albuquerque, NM 87102-3289

EXHIBIT 32.2

CERTIFICATION PURSUANT TO 18 U.S.C. § 1350, AS ADOPTED PURSUANT TO § 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q for the period ended September 30, 2021, for Public Service Company of New Mexico (“Company”), as filed with the Securities and Exchange Commission on October 28, 2021 (“Report”), each of the undersigned officers of the Company certifies, pursuant to 18 U.S.C. §1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1)the Report fully complies with the requirements of § 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2)the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	October 28, 2021	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			President and Chief Executive Officer
			Public Service Company of New Mexico
		By:	/s/ Joseph D. Tarry
			Joseph D. Tarry
			Senior Vice President and
			Chief Financial Officer
			Public Service Company of New Mexico

EX-32.3

Texas-New Mexico Power Company

577 N. Garden Ridge Blvd.

Lewisville, Texas 75067

EXHIBIT 32.3

CERTIFICATION PURSUANT TO 18 U.S.C. § 1350, AS ADOPTED PURSUANT TO § 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q for the period ended September 30, 2021, for Texas-New Mexico Power Company (“Company”), as filed with the Securities and Exchange Commission on October 28, 2021 (“Report”), each of the undersigned officers of the Company certifies, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1)the Report fully complies with the requirements of § 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2)the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	October 28, 2021	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			Chief Executive Officer
			Texas-New Mexico Power Company
		By:	/s/ Joseph D. Tarry
			Joseph D. Tarry
			Senior Vice President and
			Chief Financial Officer
			Texas-New Mexico Power Company

XML

Cover Page - shares	9 Months Ended
	Sep. 30, 2021	Oct. 22, 2021
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2021
Entity Registrant Name	PNM Resources, Inc.
Entity Incorporation, State or Country Code	NM
Entity Address, Address Line One	414 Silver Ave. SW
Entity Address, City or Town	Albuquerque
Entity Address, State or Province	NM
Entity Address, Postal Zip Code	87102-3289
City Area Code	505
Local Phone Number	241-2700
Entity File Number	001-32462
Entity Tax Identification Number	85-0468296
Title of 12(b) Security	Common Stock, no par value
Trading Symbol	PNM
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)		85,834,874
Entity Central Index Key	0001108426
Document Fiscal Year Focus	2021
Current Fiscal Year End Date	--12-31
Document Fiscal Period Focus	Q3
Amendment Flag	false
Document Transition Report	false
PNM
Entity Information [Line Items]
Entity Registrant Name	Public Service Company of New Mexico
Entity Address, Address Line One	414 Silver Ave. SW
Entity Address, City or Town	Albuquerque
Entity Address, State or Province	NM
Entity Address, Postal Zip Code	87102-3289
City Area Code	505
Local Phone Number	241-2700
Entity File Number	001-06986
Entity Tax Identification Number	85-0019030
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding (in shares)		39,117,799
Entity Central Index Key	0000081023
Current Fiscal Year End Date	--12-31
Texas-New Mexico Power Company
Entity Information [Line Items]
Entity Registrant Name	Texas-New Mexico Power Company
Entity Address, Address Line One	577 N. Garden Ridge Blvd.
Entity Address, City or Town	Lewisville
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	75067
City Area Code	972
Local Phone Number	420-4189
Entity File Number	002-97230
Entity Tax Identification Number	75-0204070
Entity Current Reporting Status	No
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding (in shares)		6,358
Entity Central Index Key	0000022767
Current Fiscal Year End Date	--12-31

XML

Condensed Consolidated Statements of Earnings - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Electric Operating Revenues:
Contracts with customers	$ 481,881	$ 455,120	$ 1,197,359	$ 1,121,177
Alternative revenue programs	(9,483)	(12,376)	(3,156)	(7,484)
Other electric operating revenue	82,153	29,721	151,595	50,043
Total electric operating revenues	554,551	472,465	1,345,798	1,163,736
Operating Expenses:
Administrative and general	56,520	51,611	168,458	148,096
Regulatory disallowances and restructuring costs	436	0	436	0
Depreciation and amortization	71,438	68,400	212,039	207,395
Transmission and distribution costs	19,996	18,742	56,166	54,062
Taxes other than income taxes	22,678	20,768	65,440	62,815
Total operating expenses	402,822	324,660	1,076,700	897,043
Operating income	151,729	147,805	269,098	266,693
Other Income and Deductions:
Interest income	3,329	3,180	10,466	9,674
Gains on investment securities	1,948	14,401	16,108	3,172
Other income	5,686	7,022	14,592	13,728
Other (deductions)	(5,098)	(7,361)	(13,836)	(14,141)
Net other income and deductions	5,865	17,242	27,330	12,433
Interest Charges	23,244	27,263	73,247	88,785
Earnings before Income Taxes	134,350	137,784	223,181	190,341
Income Taxes	16,668	12,331	26,533	14,726
Net Earnings	117,682	125,453	196,648	175,615
(Earnings) Attributable to Valencia Non-controlling Interest	(4,229)	(3,553)	(11,643)	(11,222)
Preferred Stock Dividend Requirements of Subsidiary	(132)	(132)	(396)	(396)
Net Earnings Available for PNM Common Stock	$ 113,321	$ 121,768	$ 184,609	$ 163,997
Net Earnings Attributable to PNMR per Common Share:
Basic (dollars per share)	$ 1.32	$ 1.52	$ 2.14	$ 2.05
Diluted (dollars per share)	1.32	1.52	2.14	2.05
Dividends Declared per Common Share (dollars per share)	$ 0.3275	$ 0.3075	$ 0.9825	$ 0.9225
Cost of energy
Electric Operating Revenues:
Total electric operating revenues	$ 554,551	$ 472,465	$ 1,345,798	$ 1,163,736
Operating Expenses:
Energy costs	199,380	133,991	467,452	326,564
Energy production costs
Operating Expenses:
Energy costs	32,374	31,148	106,709	98,111
PNM
Electric Operating Revenues:
Contracts with customers	361,701	341,850	884,559	825,759
Alternative revenue programs	(8,331)	(7,067)	(5,469)	(2,377)
Other electric operating revenue	82,153	29,721	151,595	50,043
Total electric operating revenues	435,523	364,504	1,030,685	873,425
Operating Expenses:
Administrative and general	49,906	45,538	143,176	132,257
Regulatory disallowances and restructuring costs	436	0	436	0
Depreciation and amortization	42,673	40,509	127,111	123,721
Transmission and distribution costs	12,844	12,075	34,906	34,265
Taxes other than income taxes	11,825	10,410	35,411	34,651
Total operating expenses	320,960	247,964	831,305	673,697
Operating income	114,563	116,540	199,380	199,728
Other Income and Deductions:
Interest income	3,364	3,239	10,376	9,882
Gains on investment securities	1,948	14,401	16,108	3,172
Other income	2,940	2,752	8,232	6,019
Other (deductions)	(3,530)	(5,590)	(10,635)	(10,700)
Net other income and deductions	4,722	14,802	24,081	8,373
Interest Charges	12,509	14,747	38,441	51,554
Earnings before Income Taxes	106,776	116,595	185,020	156,547
Income Taxes	15,500	13,591	26,178	16,127
Net Earnings	91,276	103,004	158,842	140,420
(Earnings) Attributable to Valencia Non-controlling Interest	(4,229)	(3,553)	(11,643)	(11,222)
Preferred Stock Dividend Requirements of Subsidiary	(132)	(132)	(396)	(396)
Net Earnings Attributable to PNMR	87,047	99,451	147,199	129,198
Net Earnings Available for PNM Common Stock	86,915	99,319	146,803	128,802
PNM | Cost of energy
Operating Expenses:
Energy costs	170,902	108,284	383,556	250,692
PNM | Energy production costs
Operating Expenses:
Energy costs	32,374	31,148	106,709	98,111
Texas-New Mexico Power Company
Electric Operating Revenues:
Contracts with customers	120,180	113,270	312,800	295,418
Alternative revenue programs	(1,152)	(5,309)	2,313	(5,107)
Other electric operating revenue	0	0	0	0
Total electric operating revenues	119,028	107,961	315,113	290,311
Operating Expenses:
Administrative and general	11,708	11,868	34,960	33,398
Depreciation and amortization	23,031	22,492	67,696	66,696
Transmission and distribution costs	7,152	6,667	21,260	19,797
Taxes other than income taxes	9,817	9,448	26,730	25,249
Total operating expenses	80,186	76,182	234,542	221,012
Operating income	38,842	31,779	80,571	69,299
Other Income and Deductions:
Other income	2,144	3,546	4,853	6,245
Other (deductions)	(1,000)	(1,260)	(1,602)	(1,435)
Net other income and deductions	1,144	2,286	3,251	4,810
Interest Charges	8,403	7,942	25,155	22,475
Earnings before Income Taxes	31,583	26,123	58,667	51,634
Income Taxes	3,642	2,202	6,341	4,447
Net Earnings			52,326	47,187
Net Earnings Attributable to PNMR	27,941	23,921	52,326	47,187
Texas-New Mexico Power Company | Cost of energy
Operating Expenses:
Energy costs	$ 28,478	$ 25,707	$ 83,896	$ 75,872

XML

Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Net Earnings	$ 117,682	$ 125,453	$ 196,648	$ 175,615
Unrealized Gains on Available-for-Sale Debt Securities:
Unrealized holding gains arising during the period, net of income tax (expense)	(968)	3,755	(722)	11,004
Reclassification adjustment for (gains) included in net earnings, net of income tax expense	(1,856)	(3,056)	(6,058)	(5,338)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience (gains) losses recognized as net periodic benefit cost, net of income tax expense (benefit)	1,557	1,548	4,671	4,644
Fair Value Adjustment for Cash Flow Hedges:
Change in fair market value, net of income tax (expense) of $0, $(313), $(458), and $(9)	0	918	1,346	24
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $0, $157, $229, and $284	0	(460)	(674)	(833)
Total Other Comprehensive Income (Loss)	(1,267)	2,705	(1,437)	9,501
Comprehensive Income	116,415	128,158	195,211	185,116
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(4,229)	(3,553)	(11,643)	(11,222)
Preferred Stock Dividend Requirements of Subsidiary	(132)	(132)	(396)	(396)
Comprehensive Income Attributable to PNMR	112,054	124,473	183,172	173,498
PNM
Net Earnings	91,276	103,004	158,842	140,420
Unrealized Gains on Available-for-Sale Debt Securities:
Unrealized holding gains arising during the period, net of income tax (expense)	(968)	3,755	(722)	11,004
Reclassification adjustment for (gains) included in net earnings, net of income tax expense	(1,856)	(3,056)	(6,058)	(5,338)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience (gains) losses recognized as net periodic benefit cost, net of income tax expense (benefit)	1,557	1,548	4,671	4,644
Fair Value Adjustment for Cash Flow Hedges:
Total Other Comprehensive Income (Loss)	(1,267)	2,247	(2,109)	10,310
Comprehensive Income	90,009	105,251	156,733	150,730
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(4,229)	(3,553)	(11,643)	(11,222)
Comprehensive Income Attributable to PNMR	$ 85,780	$ 101,698	$ 145,090	$ 139,508

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Condensed Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Unrealized holding gains (losses) arising during the period, income tax (expense) benefit	$ 329	$ (1,278)	$ 246	$ (3,746)
Reclassification adjustment for (gains) losses included in net earnings, income tax expense (benefit)	632	1,041	2,062	1,818
Pension liability adjustment, income tax expense (benefit)	(530)	(527)	(1,590)	(1,581)
Change in fair market value, net of income tax (expense) benefit of $311 and $(472)	0	(313)	(458)	(9)
Reclassification adjustment for (gains) losses included in net earnings, net of income tax expense (benefit) of $(68) and $13	0	157	229	284
PNM
Unrealized holding gains (losses) arising during the period, income tax (expense) benefit	329	(1,278)	246	(3,746)
Reclassification adjustment for (gains) losses included in net earnings, income tax expense (benefit)	632	1,041	2,062	1,818
Pension liability adjustment, income tax expense (benefit)	$ (530)	$ (527)	$ (1,590)	$ (1,581)

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Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Cash Flows From Operating Activities:
Net earnings	$ 196,648	$ 175,615
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	238,963	233,537
Deferred income tax expense	25,293	13,804
(Gains) on investment securities	(16,108)	(3,172)
Stock based compensation expense	6,728	6,560
Regulatory disallowances and restructuring costs	436	0
Allowance for equity funds used during construction	(8,867)	(6,728)
Other, net	4,594	3,107
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(46,649)	(57,340)
Materials, supplies, and fuel stock	(333)	10,495
Other current assets	(20,005)	(9,885)
Other assets	17,551	22,608
Accounts payable	5,934	(8,116)
Accrued interest and taxes	7,713	(3,765)
Other current liabilities	17,679	16,755
Other liabilities	(21,065)	(25,518)
Net cash flows from operating activities	408,512	367,957
Cash Flows From Investing Activities:
Additions to utility plant and non-utility plant	(496,185)	(495,334)
Proceeds from sales of investment securities	396,870	489,218
Purchases of investment securities	(405,142)	(498,170)
Investments in NMRD	0	(23,250)
Distributions from NMRD	572	0
Other, net	108	166
Net cash flows used in investing activities	(503,777)	(527,370)
Cash Flows From Financing Activities:
Short-term borrowings, net	0	494
Revolving credit facilities borrowings, net	(18,100)	(1,300)
Long-term borrowings	1,370,000	1,037,845
Repayment of long-term debt	(1,165,000)	(752,845)
Proceeds from stock option exercise	0	24
Awards of common stock	(10,082)	(11,984)
Dividends paid	(84,729)	(73,876)
Valencia’s transactions with its owner	(14,238)	(14,995)
Transmission interconnection and security deposit arrangements	31,878	8,614
Refunds paid under transmission interconnection arrangements	(9,752)	(4,400)
Debt issuance costs and other, net	(3,159)	(1,104)
Net cash flows from financing activities	96,818	186,473
Change in Cash, Restricted Cash, and Equivalents	1,553	27,060
Cash, Restricted Cash, and Equivalents at Beginning of Period	47,928	3,833
Cash, Restricted Cash, and Equivalents at End of Period	49,481	30,893
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	69,965	84,139
Income taxes paid (refunded), net	892	969
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	63,281	10,318
PNM
Cash Flows From Operating Activities:
Net earnings	158,842	140,420
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	151,775	147,790
Deferred income tax expense	24,034	16,607
(Gains) on investment securities	(16,108)	(3,172)
Regulatory disallowances and restructuring costs	436	0
Allowance for equity funds used during construction	(6,655)	(4,229)
Other, net	3,488	4,382
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(34,110)	(46,312)
Materials, supplies, and fuel stock	143	10,945
Other current assets	(20,398)	(5,661)
Other assets	14,541	19,184
Accounts payable	14,411	(2,481)
Accrued interest and taxes	13,370	564
Other current liabilities	12,442	9,022
Other liabilities	(34,394)	(30,820)
Net cash flows from operating activities	281,817	256,239
Cash Flows From Investing Activities:
Additions to utility plant and non-utility plant	(247,064)	(251,873)
Proceeds from sales of investment securities	396,870	489,218
Purchases of investment securities	(405,142)	(498,170)
Other, net	108	167
Net cash flows used in investing activities	(255,228)	(260,658)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings, net	(10,000)	(36,300)
Long-term borrowings	235,000	852,845
Repayment of long-term debt	(200,000)	(752,845)
Dividends paid	(60,396)	(41,049)
Valencia’s transactions with its owner	(14,238)	(14,995)
Transmission interconnection and security deposit arrangements	28,278	2,212
Refunds paid under transmission interconnection arrangements	(2,450)	(4,400)
Debt issuance costs and other, net	(1,665)	1,077
Net cash flows from financing activities	(25,471)	6,545
Change in Cash, Restricted Cash, and Equivalents	1,118	2,126
Cash, Restricted Cash, and Equivalents at Beginning of Period	31,446	1,001
Cash, Restricted Cash, and Equivalents at End of Period	32,564	3,127
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	33,189	45,614
Income taxes paid (refunded), net	0	0
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	45,441	3,955
Texas-New Mexico Power Company
Cash Flows From Operating Activities:
Net earnings	52,326	47,187
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	68,378	67,595
Deferred income tax expense	(6,377)	(10,737)
Allowance for equity funds used during construction	(2,212)	(2,499)
Other, net	60	33
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(12,539)	(11,029)
Materials, supplies, and fuel stock	(476)	(450)
Other current assets	(4,927)	(570)
Other assets	5,168	5,910
Accounts payable	(4,050)	952
Accrued interest and taxes	10,800	12,326
Other current liabilities	(754)	830
Other liabilities	11,538	4,258
Net cash flows from operating activities	116,935	113,806
Cash Flows From Investing Activities:
Additions to utility plant and non-utility plant	(233,381)	(228,976)
Net cash flows used in investing activities	(233,381)	(228,976)
Cash Flows From Financing Activities:
Short-term borrowings, net	0	494
Revolving credit facilities borrowings, net	0	(15,000)
Long-term borrowings	65,000	185,000
Equity contribution from parent	52,000	0
Dividends paid	0	(34,613)
Transmission interconnection and security deposit arrangements	3,600	6,402
Refunds paid under transmission interconnection arrangements	(7,302)	0
Debt issuance costs and other, net	(736)	(2,113)
Net cash flows from financing activities	112,562	140,170
Change in Cash, Restricted Cash, and Equivalents	(3,884)	25,000
Cash, Restricted Cash, and Equivalents at Beginning of Period	14,800	1,000
Cash, Restricted Cash, and Equivalents at End of Period	10,916	26,000
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	25,085	22,340
Income taxes paid (refunded), net	892	969
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	$ 14,166	$ 1,443

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Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Current Assets:
Cash and cash equivalents	$ 49,481	$ 47,928
Accounts receivable, net of allowance for credit losses	140,826	113,410
Unbilled revenues	64,874	55,504
Other receivables	28,788	23,797
Materials, supplies, and fuel stock	66,750	66,417
Regulatory assets	34,187	202
Income taxes receivable	5,323	5,672
Other current assets	57,484	64,549
Total current assets	447,713	377,479
Other Property and Investments:
Investment securities	455,409	440,115
Equity investment in NMRD	89,065	90,655
Other investments	148	284
Non-utility property, net	25,547	24,075
Total other property and investments	570,169	555,129
Utility Plant:
Plant in service, held for future use, and to be abandoned	8,723,398	8,480,799
Less accumulated depreciation and amortization	2,951,721	2,835,170
Net plant in service and plant held for future use	5,771,677	5,645,629
Construction work in progress	350,090	218,719
Nuclear fuel, net of accumulated amortization	97,055	100,801
Net utility plant	6,218,822	5,965,149
Deferred Charges and Other Assets:
Regulatory assets	544,432	557,790
Goodwill	278,297	278,297
Operating lease right-of-use assets, net of accumulated amortization	85,956	105,133
Other deferred charges	110,681	100,877
Total deferred charges and other assets	1,019,366	1,042,097
Assets	8,256,070	7,939,854
Current Liabilities:
Short-term debt	13,900	32,000
Current installments of long-term debt	104,258	575,518
Accounts payable	111,970	169,317
Customer deposits	4,876	6,606
Accrued interest and taxes	75,571	68,206
Regulatory liabilities	13,381	7,471
Operating lease liabilities	28,230	27,460
Dividends declared	28,243	28,243
Transmission interconnection arrangement liabilities	30,983	6,883
Other current liabilities	63,795	55,958
Total current liabilities	475,207	977,662
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	3,395,975	2,719,632
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	744,856	694,512
Regulatory liabilities	855,855	850,228
Asset retirement obligations	192,132	183,421
Accrued pension liability and postretirement benefit cost	46,857	58,101
Operating lease liabilities	55,106	81,065
Other deferred credits	277,189	255,230
Total deferred credits and other liabilities	2,171,995	2,122,557
Total liabilities	6,043,177	5,819,851
Commitments and Contingencies (Note 11)
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
Company common stockholders’ equity:
Common stock	1,426,587	1,429,941
Accumulated other comprehensive income (loss), net of income taxes	(80,620)	(79,183)
Retained earnings	798,983	698,707
Total stockholders' equity	2,144,950	2,049,465
Non-controlling interest in Valencia	56,414	59,009
Total equity	2,201,364	2,108,474
Total liabilities and stockholders' equity	8,256,070	7,939,854
PNM
Current Assets:
Cash and cash equivalents	32,564	31,446
Accounts receivable, net of allowance for credit losses	106,427	88,239
Unbilled revenues	49,782	43,724
Other receivables	27,836	21,814
Affiliate receivables	8,895	8,819
Materials, supplies, and fuel stock	60,330	60,472
Regulatory assets	28,387	0
Income taxes receivable	13,562	15,706
Other current assets	49,501	51,908
Total current assets	377,284	322,128
Other Property and Investments:
Investment securities	455,409	440,115
Other investments	12	120
Non-utility property, net	10,536	9,505
Total other property and investments	465,957	449,740
Utility Plant:
Plant in service, held for future use, and to be abandoned	6,134,271	6,022,753
Less accumulated depreciation and amortization	2,232,911	2,158,915
Net plant in service and plant held for future use	3,901,360	3,863,838
Construction work in progress	201,612	148,962
Nuclear fuel, net of accumulated amortization	97,055	100,801
Net utility plant	4,200,027	4,113,601
Deferred Charges and Other Assets:
Regulatory assets	452,596	457,953
Goodwill	51,632	51,632
Operating lease right-of-use assets, net of accumulated amortization	79,808	97,461
Other deferred charges	95,872	88,518
Total deferred charges and other assets	679,908	695,564
Assets	5,723,176	5,581,033
Current Liabilities:
Short-term debt	0	10,000
Current installments of long-term debt	104,258	345,570
Accounts payable	90,020	121,050
Affiliate payables	5,336	14,058
Customer deposits	4,876	6,606
Accrued interest and taxes	43,856	32,630
Regulatory liabilities	13,381	5,419
Operating lease liabilities	26,166	25,130
Dividends declared	132	132
Transmission interconnection arrangement liabilities	30,983	6,883
Other current liabilities	38,114	26,854
Total current liabilities	357,122	594,332
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	1,628,184	1,351,050
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	619,003	579,150
Regulatory liabilities	661,272	664,873
Asset retirement obligations	191,384	182,718
Accrued pension liability and postretirement benefit cost	46,157	56,273
Operating lease liabilities	51,233	75,941
Other deferred credits	211,441	201,415
Total deferred credits and other liabilities	1,780,490	1,760,370
Total liabilities	3,765,796	3,705,752
Commitments and Contingencies (Note 11)
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
Company common stockholders’ equity:
Common stock	1,494,918	1,494,918
Accumulated other comprehensive income (loss), net of income taxes	(80,620)	(78,511)
Retained earnings	475,139	388,336
Total stockholders' equity	1,889,437	1,804,743
Non-controlling interest in Valencia	56,414	59,009
Total equity	1,945,851	1,863,752
Total liabilities and stockholders' equity	5,723,176	5,581,033
Texas-New Mexico Power Company
Current Assets:
Cash and cash equivalents	10,916	14,800
Accounts receivable, net of allowance for credit losses	34,399	25,171
Unbilled revenues	15,092	11,780
Other receivables	2,917	3,703
Materials, supplies, and fuel stock	6,420	5,945
Regulatory assets	5,800	202
Other current assets	2,142	1,738
Total current assets	77,686	63,339
Other Property and Investments:
Other investments	136	164
Non-utility property, net	13,777	13,298
Total other property and investments	13,913	13,462
Utility Plant:
Plant in service, held for future use, and to be abandoned	2,320,978	2,193,270
Less accumulated depreciation and amortization	566,104	537,707
Net plant in service and plant held for future use	1,754,874	1,655,563
Construction work in progress	134,895	61,359
Net utility plant	1,889,769	1,716,922
Deferred Charges and Other Assets:
Regulatory assets	91,836	99,837
Goodwill	226,665	226,665
Operating lease right-of-use assets, net of accumulated amortization	5,778	7,206
Other deferred charges	5,912	5,149
Total deferred charges and other assets	330,191	338,857
Assets	2,311,559	2,132,580
Current Liabilities:
Accounts payable	15,404	33,620
Affiliate payables	3,982	5,883
Accrued interest and taxes	52,338	41,538
Regulatory liabilities	0	2,052
Operating lease liabilities	1,988	2,193
Other current liabilities	6,668	4,486
Total current liabilities	80,380	89,772
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	918,074	853,673
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	147,997	145,369
Regulatory liabilities	194,583	185,355
Asset retirement obligations	748	703
Accrued pension liability and postretirement benefit cost	700	1,828
Operating lease liabilities	3,579	4,779
Other deferred credits	35,494	25,423
Total deferred credits and other liabilities	383,101	363,457
Total liabilities	1,381,555	1,306,902
Commitments and Contingencies (Note 11)
Company common stockholders’ equity:
Common stock	64	64
Paid-in-capital	737,166	685,166
Retained earnings	192,774	140,448
Total stockholders' equity	930,004	825,678
Total liabilities and stockholders' equity	$ 2,311,559	$ 2,132,580

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Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Allowance for uncollectible accounts	$ 11,237	$ 8,333
Accumulated depreciation, nuclear fuel	$ 48,062	$ 41,367
Cumulative preferred stock of subsidiary, stated value (in dollars per share)	$ 100	$ 100
Cumulative preferred stock of subsidiary, shares authorized (in shares)	10,000,000	10,000,000
Cumulative preferred stock of subsidiary, shares issued (in shares)	115,293	115,293
Cumulative preferred stock of subsidiary, shares outstanding (in shares)	115,293	115,293
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized (in shares)	120,000,000	120,000,000
Common stock, shares issued (in shares)	85,834,874	85,834,874
Common stock, shares outstanding (in shares)	85,834,874	85,834,874
PNM
Allowance for uncollectible accounts	$ 11,237	$ 8,333
Accumulated depreciation, nuclear fuel	$ 48,062	$ 41,367
Cumulative preferred stock, stated value (in dollars per share)	$ 100	$ 100
Cumulative preferred stock, shares authorized (in shares)	10,000,000	10,000,000
Cumulative preferred stock, shares issued (in shares)	115,293	115,293
Cumulative preferred stock, shares outstanding (in shares)	115,293	115,293
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized (in shares)	40,000,000	40,000,000
Common stock, shares issued (in shares)	39,117,799	39,117,799
Common stock, shares outstanding (in shares)	39,117,799	39,117,799
Texas-New Mexico Power Company
Common stock, par value (in dollars per share)	$ 10	$ 10
Common stock, shares authorized (in shares)	12,000,000	12,000,000
Common stock, shares issued (in shares)	6,358	6,358
Common stock, shares outstanding (in shares)	6,358	6,358

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Condensed Consolidated Statements of Changes in Equity - USD ($)	Total	Total PNMR Common Stockholders’ Equity	Common Stock	AOCI	Retained Earnings	Non- controlling Interest in Valencia	PNM	PNM Total PNMR Common Stockholders’ Equity	PNM Common Stock	PNM AOCI	PNM Retained Earnings	PNM Non- controlling Interest in Valencia	Texas-New Mexico Power Company	Texas-New Mexico Power Company Common Stock	Texas-New Mexico Power Company Paid-in Capital	Texas-New Mexico Power Company Retained Earnings
Beginning balance at Dec. 31, 2019	$ 1,741,750,000	$ 1,678,698,000	$ 1,150,552,000	$ (99,377,000)	$ 627,523,000	$ 63,052,000	$ 1,512,431,000	$ 1,449,379,000	$ 1,264,918,000	$ (99,055,000)	$ 283,516,000	$ 63,052,000
Beginning balance TNMP at Dec. 31, 2019													$ 754,627,000	$ 64,000	$ 614,166,000	$ 140,397,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings before subsidiary preferred stock dividends	175,615,000	164,393,000			164,393,000	11,222,000	140,420,000	129,198,000			129,198,000	11,222,000	47,187,000
Net earnings							129,198,000						47,187,000			47,187,000
Total other comprehensive income (loss)	9,501,000	9,501,000		9,501,000			10,310,000	10,310,000		10,310,000
Subsidiary preferred stock dividends	(396,000)	(396,000)			(396,000)
Dividends declared on preferred stock							(396,000)	(396,000)			(396,000)
Dividends declared on common stock	(73,480,000)	(73,480,000)			(73,480,000)		(40,654,000)	(40,654,000)			(40,654,000)		(34,613,000)			(34,613,000)
Proceeds from stock option exercise	24,000	24,000	24,000
Awards of common stock	(11,984,000)	(11,984,000)	(11,984,000)
Stock based compensation expense	6,560,000	6,560,000	6,560,000
Valencia’s transactions with its owner	(14,995,000)					(14,995,000)	(14,995,000)					(14,995,000)
Ending balance at Sep. 30, 2020	1,832,595,000	1,773,316,000	1,145,152,000	(89,876,000)	718,040,000	59,279,000	1,607,116,000	1,547,837,000	1,264,918,000	(88,745,000)	371,664,000	59,279,000
Ending balance TNMP at Sep. 30, 2020													767,201,000	64,000	614,166,000	152,971,000
Beginning balance at Jun. 30, 2020	1,756,427,000	1,696,500,000	1,143,822,000	(92,581,000)	645,259,000	59,927,000	1,506,198,000	1,446,271,000	1,264,918,000	(90,992,000)	272,345,000	59,927,000
Beginning balance TNMP at Jun. 30, 2020													759,454,000	64,000	614,166,000	145,224,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings before subsidiary preferred stock dividends	125,453,000	121,900,000			121,900,000	3,553,000	103,004,000	99,451,000			99,451,000	3,553,000
Net earnings							99,451,000						23,921,000			23,921,000
Total other comprehensive income (loss)	2,705,000	2,705,000		2,705,000			2,247,000	2,247,000		2,247,000
Subsidiary preferred stock dividends	(132,000)	(132,000)			(132,000)
Dividends declared on preferred stock							(132,000)	(132,000)			(132,000)
Dividends declared on common stock	(48,987,000)	(48,987,000)			(48,987,000)		0						(16,174,000)			(16,174,000)
Stock based compensation expense	1,330,000	1,330,000	1,330,000
Valencia’s transactions with its owner	(4,201,000)					(4,201,000)	(4,201,000)					(4,201,000)
Ending balance at Sep. 30, 2020	1,832,595,000	1,773,316,000	1,145,152,000	(89,876,000)	718,040,000	59,279,000	1,607,116,000	1,547,837,000	1,264,918,000	(88,745,000)	371,664,000	59,279,000
Ending balance TNMP at Sep. 30, 2020													767,201,000	64,000	614,166,000	152,971,000
Beginning balance at Dec. 31, 2020	2,108,474,000	2,049,465,000	1,429,941,000	(79,183,000)	698,707,000	59,009,000	1,863,752,000	1,804,743,000	1,494,918,000	(78,511,000)	388,336,000	59,009,000
Beginning balance TNMP at Dec. 31, 2020	2,049,465,000						1,804,743,000						825,678,000	64,000	685,166,000	140,448,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings before subsidiary preferred stock dividends	196,648,000	185,005,000			185,005,000	11,643,000	158,842,000	147,199,000			147,199,000	11,643,000	52,326,000
Net earnings							147,199,000						52,326,000			52,326,000
Total other comprehensive income (loss)	(1,437,000)	(1,437,000)		(1,437,000)			(2,109,000)	(2,109,000)		(2,109,000)
Equity contribution from parent													52,000,000		52,000,000
Subsidiary preferred stock dividends	(396,000)	(396,000)			(396,000)
Dividends declared on preferred stock							(396,000)	(396,000)			(396,000)
Dividends declared on common stock	(84,333,000)	(84,333,000)			(84,333,000)		(60,000,000)	(60,000,000)			(60,000,000)
Awards of common stock	(10,082,000)	(10,082,000)	(10,082,000)
Stock based compensation expense	6,728,000	6,728,000	6,728,000
Valencia’s transactions with its owner	(14,238,000)					(14,238,000)	(14,238,000)					(14,238,000)
Ending balance at Sep. 30, 2021	2,201,364,000	2,144,950,000	1,426,587,000	(80,620,000)	798,983,000	56,414,000	1,945,851,000	1,889,437,000	1,494,918,000	(80,620,000)	475,139,000	56,414,000
Ending balance TNMP at Sep. 30, 2021	2,144,950,000						1,889,437,000						930,004,000	64,000	737,166,000	192,774,000
Beginning balance at Jun. 30, 2021	2,145,398,000	2,088,231,000	1,425,700,000	(79,353,000)	741,884,000	57,167,000	1,920,956,000	1,863,789,000	1,494,918,000	(79,353,000)	448,224,000	57,167,000
Beginning balance TNMP at Jun. 30, 2021													902,063,000	64,000	737,166,000	164,833,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings before subsidiary preferred stock dividends	117,682,000	113,453,000			113,453,000	4,229,000	91,276,000	87,047,000			87,047,000	4,229,000
Net earnings							87,047,000						27,941,000			27,941,000
Total other comprehensive income (loss)	(1,267,000)	(1,267,000)		(1,267,000)			(1,267,000)	(1,267,000)		(1,267,000)
Subsidiary preferred stock dividends	(132,000)	(132,000)			(132,000)
Dividends declared on preferred stock							(132,000)	(132,000)			(132,000)
Dividends declared on common stock	(56,222,000)	(56,222,000)			(56,222,000)		(60,000,000)	(60,000,000)			(60,000,000)
Awards of common stock	(129,000)	(129,000)	(129,000)
Stock based compensation expense	1,016,000	1,016,000	1,016,000
Valencia’s transactions with its owner	(4,982,000)					(4,982,000)	(4,982,000)					(4,982,000)
Ending balance at Sep. 30, 2021	2,201,364,000	$ 2,144,950,000	$ 1,426,587,000	$ (80,620,000)	$ 798,983,000	$ 56,414,000	1,945,851,000	$ 1,889,437,000	$ 1,494,918,000	$ (80,620,000)	$ 475,139,000	$ 56,414,000
Ending balance TNMP at Sep. 30, 2021	$ 2,144,950,000						$ 1,889,437,000						$ 930,004,000	$ 64,000	$ 737,166,000	$ 192,774,000

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Significant Accounting Policies and Responsibility for Financial Statements

9 Months Ended

Sep. 30, 2021

Accounting Policies [Abstract]

Significant Accounting Policies and Responsibility for Financial Statements

Significant Accounting Policies and Responsibility for Financial Statements

Financial Statement Preparation

In the opinion of management, the accompanying unaudited interim Condensed Consolidated Financial Statements reflect all normal and recurring accruals and adjustments that are necessary to present fairly the consolidated financial position at September 30, 2021 and December 31, 2020, and the consolidated results of operations and comprehensive income for the three and nine months ended September 30, 2021 and 2020 and cash flows for the nine months ended September 30, 2021 and 2020. 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. Weather causes the Company’s results of operations to be seasonal in nature and the results of operations presented in the accompanying Condensed Consolidated Financial Statements are not necessarily representative of operations for an entire year.

The Notes to Condensed Consolidated Financial Statements include disclosures for PNMR, PNM, and TNMP. This report uses the term “Company” when discussing matters of common applicability to PNMR, PNM, and TNMP. Discussions regarding only PNMR, PNM, or TNMP are so indicated. Certain amounts in the 2020 Condensed Consolidated Financial Statements and Notes thereto have been reclassified to conform to the 2021 financial statement presentation.

These Condensed Consolidated Financial Statements are unaudited. Certain information and note disclosures normally included in the annual audited Consolidated Financial Statements have been condensed or omitted, as permitted under the applicable rules and regulations. Readers of these financial statements should refer to PNMR’s, PNM’s, and TNMP’s audited Consolidated Financial Statements and Notes thereto that are included in their respective 2020 Annual Reports on Form 10-K.

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 Condensed Consolidated Financial Statements of each of PNMR, PNM, and TNMP include their accounts and those of subsidiaries in which that entity owns a majority voting interest. PNM also consolidates Valencia. See Note 6. PNM owns undivided interests in several 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 PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as equity transactions, and interconnection billings. See Note 15. All intercompany transactions and balances have been eliminated.

Dividends on Common Stock

Dividends on PNMR’s common stock are declared by the Board. The timing of the declaration of dividends is dependent on the timing of meetings and other actions of the Board. This has historically resulted in dividends attributable to the second quarter of each year being declared through actions of the Board during the third quarter of the year. The Board declared dividends on common stock considered to be for the second quarter of $0.3275 per share in July 2021 and $0.3075 per share in July 2020, which are reflected as being in the second quarter within "Dividends Declared per Common Share" on the PNMR Condensed Consolidated Statements of Earnings. The Board declared dividends on common stock for the third quarter of $0.3275 per share in September 2021 and $0.3075 per share in September 2020, which are reflected as being in the third quarter within "Dividends Declared per Common Share" on the PNMR Condensed Consolidated Statement of Earnings.

In the three and nine months ended September 30, 2021, PNMR made equity contributions of zero and $52.0 million to TNMP. PNM declared and paid cash dividends on its common stock to PNMR of $60.0 million in the three and nine months ended September 30, 2021 and zero and $40.7 million in the three and nine months ended September 30, 2020. TNMP did not declare or pay cash dividends on its common stock to PNMR in the three and nine months ended September 30, 2021. TNMP declared and paid cash dividends on its common stock to PNMR of $16.2 million and $34.6 million in the three and nine months ended September 30, 2020.

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Segment Information

9 Months Ended

Sep. 30, 2021

Segment Reporting [Abstract]

Segment Information

Segment Information

The following segment presentation is based on the methodology that management uses for making operating decisions and assessing performance of its various business activities. A reconciliation of the segment presentation to the GAAP financial statements is provided.

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, as well as providing transmission services to third parties. The sale of electricity includes the asset optimization of PNM’s jurisdictional capacity, as well as the capacity excluded from retail rates. FERC has jurisdiction over wholesale power and transmission rates.

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.

Corporate and Other

The Corporate and Other segment includes PNMR holding company activities, primarily related to corporate level debt and PNMR Services Company. The activities of PNMR Development, NM Capital, and the equity method investment in NMRD are also included in Corporate and Other. Eliminations of intercompany transactions are reflected in the Corporate and Other segment.

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

PNMR SEGMENT INFORMATION

	PNM		TNMP		Corporate and Other		PNMR Consolidated
	(In thousands)
Three Months Ended September 30, 2021
Electric operating revenues	$	435,523	$	119,028	$	—	$	554,551
Cost of energy	170,902		28,478		—		199,380
Utility margin	264,621		90,550		—		355,171
Other operating expenses	107,385		28,677		(4,058)		132,004
Depreciation and amortization	42,673		23,031		5,734		71,438
Operating income (loss)	114,563		38,842		(1,676)		151,729
Interest income (loss)	3,364		—		(35)		3,329
Other income	1,358		1,144		34		2,536
Interest charges	(12,509)		(8,403)		(2,332)		(23,244)
Segment earnings (loss) before income taxes	106,776		31,583		(4,009)		134,350
Income taxes (benefit)	15,500		3,642		(2,474)		16,668
Segment earnings (loss)	91,276		27,941		(1,535)		117,682
Valencia non-controlling interest	(4,229)		—		—		(4,229)
Subsidiary preferred stock dividends	(132)		—		—		(132)
Segment earnings (loss) attributable to PNMR	$	86,915	$	27,941	$	(1,535)	$	113,321
Nine Months Ended September 30, 2021
Electric operating revenues	$	1,030,685	$	315,113	$	—	$	1,345,798
Cost of energy	383,556		83,896		—		467,452
Utility margin	647,129		231,217		—		878,346
Other operating expenses	320,638		82,950		(6,379)		397,209
Depreciation and amortization	127,111		67,696		17,232		212,039
Operating income (loss)	199,380		80,571		(10,853)		269,098
Interest income	10,376		—		90		10,466
Other income (deductions)	13,705		3,251		(92)		16,864
Interest charges	(38,441)		(25,155)		(9,651)		(73,247)
Segment earnings (loss) before income taxes	185,020		58,667		(20,506)		223,181
Income taxes (benefit)	26,178		6,341		(5,986)		26,533
Segment earnings (loss)	158,842		52,326		(14,520)		196,648
Valencia non-controlling interest	(11,643)		—		—		(11,643)
Subsidiary preferred stock dividends	(396)		—		—		(396)
Segment earnings (loss) attributable to PNMR	$	146,803	$	52,326	$	(14,520)	$	184,609
At September 30, 2021:
Total Assets	$	5,723,176	$	2,311,559	$	221,335	$	8,256,070
Goodwill	$	51,632	$	226,665	$	—	$	278,297

	PNM		TNMP		Corporate and Other		PNMR Consolidated
	(In thousands)
Three Months Ended September 30, 2020
Electric operating revenues	$	364,504	$	107,961	$	—	$	472,465
Cost of energy	108,284		25,707		—		133,991
Utility margin	256,220		82,254		—		338,474
Other operating expenses	99,171		27,983		(4,885)		122,269
Depreciation and amortization	40,509		22,492		5,399		68,400
Operating income (loss)	116,540		31,779		(514)		147,805
Interest income	3,239		—		(59)		3,180
Other income	11,563		2,286		213		14,062
Interest charges	(14,747)		(7,942)		(4,574)		(27,263)
Segment earnings (loss) before income taxes	116,595		26,123		(4,934)		137,784
Income taxes (benefit)	13,591		2,202		(3,462)		12,331
Segment earnings (loss)	103,004		23,921		(1,472)		125,453
Valencia non-controlling interest	(3,553)		—		—		(3,553)
Subsidiary preferred stock dividends	(132)		—		—		(132)
Segment earnings (loss) attributable to PNMR	$	99,319	$	23,921	$	(1,472)	$	121,768
Nine Months Ended September 30, 2020
Electric operating revenues	$	873,425	$	290,311	$	—	$	1,163,736
Cost of energy	250,692		75,872		—		326,564
Utility margin	622,733		214,439		—		837,172
Other operating expenses	299,284		78,444		(14,644)		363,084
Depreciation and amortization	123,721		66,696		16,978		207,395
Operating income (loss)	199,728		69,299		(2,334)		266,693
Interest income	9,882		—		(208)		9,674
Other income (deductions)	(1,509)		4,810		(542)		2,759
Interest charges	(51,554)		(22,475)		(14,756)		(88,785)
Segment earnings (loss) before income taxes	156,547		51,634		(17,840)		190,341
Income taxes (benefit)	16,127		4,447		(5,848)		14,726
Segment earnings (loss)	140,420		47,187		(11,992)		175,615
Valencia non-controlling interest	(11,222)		—		—		(11,222)
Subsidiary preferred stock dividends	(396)		—		—		(396)
Segment earnings (loss) attributable to PNMR	$	128,802	$	47,187	$	(11,992)	$	163,997
At September 30, 2020:
Total Assets	$	5,449,238	$	2,075,291	$	217,583	$	7,742,112
Goodwill	$	51,632	$	226,665	$	—	$	278,297

The Company defines utility margin as electric operating revenues less cost of energy. Cost of energy consists primarily of fuel and purchase power costs for PNM and costs charged by third-party transmission providers for TNMP. The Company believes that utility margin provides a more meaningful basis for evaluating operations than electric operating revenues since substantially all such costs are offset in revenues as fuel and purchase power costs are passed through to customers under PNM’s FPPAC and third-party transmission costs are passed on to customers through TNMP’s transmission cost recovery factor. Utility margin is not a financial measure required to be presented and is considered a non-GAAP measure.

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Accumulated Other Comprehensive Income (Loss)

9 Months Ended

Sep. 30, 2021

Equity [Abstract]

Accumulated Other Comprehensive Income (Loss)

Accumulated Other Comprehensive Income (Loss)

Information regarding accumulated other comprehensive income (loss) for the nine months ended September 30, 2021 and 2020 is as follows:

	Accumulated Other Comprehensive Income (Loss)
	PNM						Corporate and Other		PNMR Consolidated
	Unrealized Gains on Available-for-Sale Debt Securities		Pension Liability Adjustment				Fair Value Adjustment for Cash Flow Hedges
					Total				Total
	(In thousands)
Balance at December 31, 2020	$	20,403	$	(98,914)	$	(78,511)	$	(672)	$	(79,183)
Amounts reclassified from AOCI (pre-tax)	(8,120)		6,261		(1,859)		(903)		(2,762)
Income tax impact of amounts reclassified	2,062		(1,590)		472		229		701
Other OCI changes (pre-tax)	(968)		—		(968)		1,804		836
Income tax impact of other OCI changes	246		—		246		(458)		(212)
Net after-tax change	(6,780)		4,671		(2,109)		672		(1,437)
Balance at September 30, 2021	$	13,623	$	(94,243)	$	(80,620)	$	—	$	(80,620)

Balance at December 31, 2019	$	10,638	$	(109,693)	$	(99,055)	$	(322)	$	(99,377)
Amounts reclassified from AOCI (pre-tax)	(7,156)		6,225		(931)		(1,117)		(2,048)
Income tax impact of amounts reclassified	1,818		(1,581)		237		284		521
Other OCI changes (pre-tax)	14,750		—		14,750		33		14,783
Income tax impact of other OCI changes	(3,746)		—		(3,746)		(9)		(3,755)
Net after-tax change	5,666		4,644		10,310		(809)		9,501
Balance at September 30, 2020	$	16,304	$	(105,049)	$	(88,745)	$	(1,131)	$	(89,876)

The Condensed 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 Condensed Consolidated Statements of Earnings.

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Earnings Per Share

9 Months Ended

Sep. 30, 2021

Earnings Per Share [Abstract]

Earnings Per Share

Earnings Per Share

Dual presentation of basic and diluted earnings per share is presented in the Condensed Consolidated Statements of Earnings of PNMR. PNMR’s potentially dilutive shares consist of restricted stock and PNMR common stock issuable in 2020 under the PNMR 2020 Forward Equity Sale Agreements, which are calculated under the treasury stock method. See Note 7 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands, except per share amounts)
Net Earnings Attributable to PNMR	$	113,321	$	121,768	$	184,609	$	163,997
Average Number of Common Shares:
Outstanding during period	85,835		79,654		85,835		79,654
Vested awards of restricted stock	237		213		230		205
Average Shares – Basic	86,072		79,867		86,065		79,859
Dilutive Effect of Common Stock Equivalents:
PNMR 2020 Forward Equity Sale Agreements	—		—		—		57
Restricted stock	41		39		41		38
Average Shares – Diluted	86,113		79,906		86,106		79,954
Net Earnings Per Share of Common Stock:
Basic	$	1.32	$	1.52	$	2.14	$	2.05
Diluted	$	1.32	$	1.52	$	2.14	$	2.05

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Electric Operating Revenues

9 Months Ended

Sep. 30, 2021

Revenue from Contract with Customer [Abstract]

Electric Operating Revenues

Electric Operating Revenues

PNMR is an investor-owned holding company with two regulated utilities providing electricity and electric services in New Mexico and Texas. PNMR’s electric utilities are PNM and TNMP.

Additional information concerning electric operating revenue is contained in Note 4 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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. As a result of the economic conditions resulting from the COVID-19 pandemic, PNM updated its allowance for accounts receivable balances and recorded incremental credit losses of $0.5 million and $2.9 million in the three and nine months ended September 30, 2021 and $2.0 million and $2.7 million in the three and nine months ended September 30, 2020. The NMPRC issued an order authorizing all public utilities to create a regulatory asset to defer incremental costs related to COVID-19, including increases in uncollectible accounts. See discussion regarding regulatory treatment in Note 12.

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 three and nine months ended September 30, 2021, PNM recorded $0.8 million in estimated credit losses related to these transactions.

In February 2021, Texas experienced a severe winter storm delivering the coldest temperatures in 100 years for many parts of the state. As a result, the ERCOT market was not able to deliver sufficient generation load to the grid resulting in significant, statewide outages as ERCOT directed transmission operators to curtail thousands of firm load megawatts. TNMP

complied with ERCOT directives to curtail delivery of electricity in its service territory and did not experience significant outages on its system outside of the ERCOT directed curtailments. During the weather event, generators experienced an extreme spike in market driven fuel prices and in turn charged REPs excessive market driven power prices which eventually get passed to end users on their electricity bill. Given the uncertainty of the collectability of end users' bills by REPs, ERCOT also increased the collateral required by REPs in order to do business within ERCOT's Balancing Authority. TNMP has deferred bad debt expense (credit losses) from defaulting REPs to a regulatory asset totaling $0.8 million at September 30, 2021 and will seek recovery in a general rate case.

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 alternative revenue program revenues ("ARP") and other revenues.

	PNM		TNMP		PNMR Consolidated
Three Months Ended September 30, 2021	(In thousands)
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	155,035	$	51,839	$	206,874
Commercial	137,071		34,434		171,505
Industrial	24,856		7,282		32,138
Public authority	7,388		1,614		9,002
Economy energy service	7,389		—		7,389
Transmission	26,459		24,075		50,534
Miscellaneous	3,503		936		4,439
Total revenues from contracts with customers	361,701		120,180		481,881
Alternative revenue programs	(8,331)		(1,152)		(9,483)
Other electric operating revenues	82,153		—		82,153
Total Electric Operating Revenues	$	435,523	$	119,028	$	554,551
Nine Months Ended September 30, 2021
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	377,794	$	121,600	$	499,394
Commercial	327,090		93,332		420,422
Industrial	66,593		21,621		88,214
Public authority	17,312		4,561		21,873
Economy energy service	24,722		—		24,722
Transmission	60,919		68,849		129,768
Miscellaneous	10,129		2,837		12,966
Total revenues from contracts with customers	884,559		312,800		1,197,359
Alternative revenue programs	(5,469)		2,313		(3,156)
Other electric operating revenues	151,595		—		151,595
Total Electric Operating Revenues	$	1,030,685	$	315,113	$	1,345,798

	PNM		TNMP		PNMR Consolidated
Three Months Ended September 30, 2020	(In thousands)
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	158,549	$	53,114	$	211,663
Commercial	125,414		31,077		156,491
Industrial	25,475		6,842		32,317
Public authority	7,982		1,468		9,450
Economy energy service	3,270		—		3,270
Transmission	17,463		19,845		37,308
Miscellaneous	3,697		924		4,621
Total revenues from contracts with customers	341,850		113,270		455,120
Alternative revenue programs	(7,067)		(5,309)		(12,376)
Other electric operating revenues	29,721		—		29,721
Total Electric Operating Revenues	$	364,504	$	107,961	$	472,465
Nine Months Ended September 30, 2020
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	370,448	$	122,315	$	492,763
Commercial	305,127		87,868		392,995
Industrial	65,313		20,232		85,545
Public authority	17,236		4,311		21,547
Economy energy service	11,802		—		11,802
Transmission	45,727		58,095		103,822
Miscellaneous	10,106		2,597		12,703
Total revenues from contracts with customers	825,759		295,418		1,121,177
Alternative revenue programs	(2,377)		(5,107)		(7,484)
Other electric operating revenues	50,043		—		50,043
Total Electric Operating Revenues	$	873,425	$	290,311	$	1,163,736

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 Condensed Consolidated Balance Sheets, net of allowance for credit losses, includes $98.6 million at September 30, 2021 and $86.2 million at December 31, 2020 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). The Company had no contract assets as of September 30, 2021 or December 31, 2020. 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. PNMR's, PNM's, and TNMP's contract liabilities and

related revenues are insignificant for all 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.

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Variable Interest Entities

9 Months Ended

Sep. 30, 2021

Variable Interest Entities [Abstract]

Variable Interest Entities

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. Additional information concerning PNM’s VIEs is contained in Note 10 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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 addition to variable operation and maintenance charges under this PPA. For the three and nine months ended September 30, 2021, PNM paid $5.0 million and $14.9 million for fixed charges and $0.7 million and $1.6 million for variable charges. For the three and nine months ended September 30, 2020, PNM paid $5.0 million and $15.0 million for fixed charges and $0.3 million and $1.2 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 Condensed Consolidated Financial Statements of PNM although PNM has no legal ownership interest or voting control of the VIE. The assets and liabilities of Valencia set forth below are immaterial to PNM and, therefore, not shown separately on the Condensed 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
	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands)
Operating revenues	$	5,719	$	5,278	$	16,425	$	16,126
Operating expenses	1,490		1,725		4,782		4,904
Earnings attributable to non-controlling interest	$	4,229	$	3,553	$	11,643	$	11,222

	Financial Position
	September 30,		December 31,
	2021		2020
	(In thousands)
Current assets	$	3,981	$	3,911
Net property, plant, and equipment	53,617		55,744
Total assets	57,598		59,655
Current liabilities	1,184		646
Owners’ equity – non-controlling interest	$	56,414	$	59,009

Westmoreland San Juan Mining, LLC

As discussed in the subheading Coal Supply in Note 11, PNM purchases coal for SJGS under the SJGS CSA. On October 9, 2018, Westmoreland filed a Current Report on Form 8-K with the SEC announcing it had filed voluntary petitions for relief under Chapter 11 of the U.S. Bankruptcy Code. On March 15, 2019, Westmoreland emerged from Chapter 11 bankruptcy as a privately held company owned and operated by a group of its former creditors. Under the reorganization, the assets of SJCC were sold to Westmoreland San Juan Mining, LLC (“WSJ LLC”), a subsidiary of Westmoreland Mining Holdings, LLC. As successor entity to SJCC, WSJ LLC assumed all rights and obligations of SJCC including obligations to PNM under the SJGS CSA and to PNMR under letter of credit support agreements.

PNMR issued $30.3 million in letters of credit to facilitate the issuance of reclamation bonds required in order for SJCC to mine coal to be supplied to SJGS. As discussed above, WSJ LLC assumed the rights and obligations of SJCC, including obligations to PNMR for the letters of credit. The letters of credit support results in PNMR having a variable interest in WSJ LLC since PNMR is subject to possible loss in the event performance by PNMR is required under the letters of credit support. PNMR 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 all reclamation costs are reimbursable under the SJGS CSA. Also, much of the mine reclamation activities will not be performed until after the expiration of the SJGS CSA. In addition, each of the SJGS participants has established and actively fund trusts to meet future reclamation obligations.

WSJ LLC is considered a VIE.  PNMR’s analysis of its arrangements with WSJ LLC concluded that WSJ LLC has the ability to direct its mining operations, which is the factor that most significantly impacts the economic performance of WSJ LLC.  Other than PNM being able to ensure that coal is supplied in adequate quantities and of sufficient quality to provide the fuel necessary to operate SJGS in a normal manner, the mining operations are solely under the control of WSJ LLC, including developing mining plans, hiring of personnel, and incurring operating and maintenance expenses. Neither PNMR nor PNM has any ability to direct or influence the mining operation.  PNM’s involvement through the SJGS CSA is a protective right rather than a participating right and WSJ LLC has the power to direct the activities that most significantly impact the economic performance of WSJ LLC.  The SJGS CSA requires WSJ LLC to deliver coal required to fuel SJGS in exchange for payment of a set price per ton, which is escalated over time for inflation.  If WSJ LLC is able to mine more efficiently than anticipated, its economic performance will be improved.  Conversely, if WSJ LLC cannot mine as efficiently as anticipated, its economic performance will be negatively impacted.  Accordingly, PNMR believes WSJ LLC is the primary beneficiary and, therefore, WSJ LLC is not consolidated by either PNMR or PNM. The amounts outstanding under the letters of credit support constitute PNMR’s maximum exposure to loss from the VIE at September 30, 2021.

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Fair Value of Derivative and Other Financial Instruments

9 Months Ended

Sep. 30, 2021

Fair Value of Derivative and Other Financial Instruments [Abstract]

Fair Value of Derivative and Other Financial Instruments

Fair Value of Derivative and Other Financial Instruments

Additional information concerning energy related derivative contracts and other financial instruments is contained in Note 9 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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.

In the third quarter of 2021, PNM entered into three agreements to purchase power from third parties at a fixed price in order to ensure that customer demand during the 2022 summer peak load period is met. Two of the agreements, the purchase of 85 MW from June through September 2022 and the purchase of 40 MW for the full year of 2022, are not considered derivatives because there are no notional amounts due to the unit-contingent nature of the agreements. The third agreement for the purchase of 150 MW firm power in June and September 2022 meets the definition of an economic hedge described below and has been accounted for accordingly.

Beginning January 1, 2018, PNM is exposed to market risk for its 65 MW interest in SJGS Unit 4, which is held as merchant plant as ordered by the NMPRC. PNM has entered into agreements to sell power from 36 MW of that capacity to a third party at a fixed price for the period January 1, 2018 through May 31, 2022, subject to certain conditions. Under these agreements, PNM is obligated to deliver 36 MW of power only when SJGS Unit 4 is operating.  These agreements are not considered derivatives because there is no notional amount due to the unit-contingent nature of the transactions.

PNM and Tri-State have a hazard sharing agreement that expires in May 2022. Under this agreement, each party sells the other party 100 MW of capacity and energy from a designated generation resource on a unit contingent basis, subject to certain performance guarantees.  Both the purchases and sales are made at the same market index price.  This agreement serves to reduce the magnitude of each party’s single largest generating hazard and assists in enhancing the reliability and efficiency of their respective operations. PNM passes the sales and purchases through to customers under PNM’s FPPAC.

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.

Unusually cold weather in February 2021 resulted in higher than expected natural gas and purchased power costs. PNM mitigated the impacts from the cold weather by securing gas supplies in advance, engaging in market purchases when lower prices were available, and adjusting plant operation of its gas units to minimize reliance on higher-priced gas supplies. PNM estimates the impact of the cold weather conditions in the first quarter of 2021 resulted in approximately $20 million of additional natural gas costs and approximately $8 million in additional purchased power costs. These fuel increases are being passed through to customers under the FPPAC over the remainder of 2021.

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 nine months ended September 30, 2021 and the year ended December 31, 2020, PNM was not hedging its exposure to the variability in future cash flows from commodity derivatives through designated cash flows 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 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 Condensed Consolidated Balance Sheets:

	Economic Hedges
	September 30, 2021		December 31, 2020
	(In thousands)
Other current assets	$	753	$	1,096
Other deferred charges	—		455
	753		1,551
Other current liabilities	(2,703)		(1,096)
Other deferred credits	—		(455)
	(2,703)		(1,551)
Net	$	(1,950)	$	—

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. Included in the table above are equal amounts of current assets and current liabilities aggregating $0.7 million at September 30, 2021. All of the assets and liabilities in the table above at December 31, 2020 result from PNM’s hazard sharing arrangements with Tri-State. The hazard sharing arrangements are net-settled upon delivery.

As discussed above, PNM has a NMPRC-approved hedging plan to manage fuel and purchased power costs related to customers covered by its FPPAC. The table above includes less than $0.1 million in current assets and $2.0 million of current liabilities related to this plan at September 30, 2021. There were no amounts hedged under this plan as of December 31, 2020.

At September 30, 2021 and December 31, 2020, PNM had no amounts recognized for the legal right to reclaim cash collateral. However, at both September 30, 2021 and December 31, 2020, amounts posted as cash collateral under margin arrangements were $0.5 million, which is included in other current assets on the Condensed Consolidated Balance Sheets. At both September 30, 2021 and December 31, 2020, obligations to return cash collateral were $0.9 million, which is included in other current liabilities and other deferred credits on the Condensed Consolidated Balance Sheets.

The effects of mark-to-market commodity derivative instruments on PNM’s revenues and cost of energy during the three and nine months ended September 30, 2021 and 2020 were less than $0.1 million. Commodity derivatives had no impact on OCI for any of the periods presented.

PNM's net buy (sell) volume positions for energy were 111,512 MWh and zero MWh at September 30, 2021 and December 31, 2020. PNM had no open gas commodity volume positions at September 30, 2021 or December 31, 2020.

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. At September 30, 2021 and December 31, 2020, PNM had no such contracts in a net liability position.

Non-Derivative Financial Instruments

The carrying amounts reflected on the Condensed 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 and trusts for PNM’s share of final reclamation costs related to the coal mines serving SJGS and Four Corners. See Note 11. At September 30, 2021 and December 31, 2020, the fair value of investment securities included $392.2 million and $379.2 million for the NDT and $63.2 million and $60.9 million for the 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. At September 30, 2021 and December 31, 2020, PNM had 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 Condensed Consolidated Statements of Earnings related to investment securities in the NDT and reclamation trusts are presented in the following table:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands)
Equity securities:
Net gains (losses) from equity securities sold	$	(309)	$	90	$	5,931	$	4,131
Net gains (losses) from equity securities still held	(3,153)		8,545		2,388		2,991
Total net gains (losses) on equity securities	(3,462)		8,635		8,319		7,122
Available-for-sale debt securities:
Net gains (losses) on debt securities	5,410		5,766		7,789		(3,950)
Net gains on investment securities	$	1,948	$	14,401	$	16,108	$	3,172

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 $0.6 million and $1.2 million for the three and nine months ended September 30, 2021 and $4.2 million and $(4.5) million for the three and nine months ended September 30, 2020.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands)
Proceeds from sales	$	128,683	$	134,567	$	396,870	$	489,218
Gross realized gains	$	10,986	$	12,998	$	30,290	$	30,085
Gross realized (losses)	$	(6,527)	$	(11,374)	$	(17,776)	$	(25,411)

At September 30, 2021, the available-for-sale debt securities held by PNM, had the following final maturities:

	Fair Value
	(In thousands)
Within 1 year	$	26,085
After 1 year through 5 years	77,703
After 5 years through 10 years	93,532
After 10 years through 15 years	21,475
After 15 years through 20 years	13,858
After 20 years	33,306
	$	265,959

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. Level 3 inputs are unobservable inputs for the asset or liability.

For investment securities, Level 2 and Level 3 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. 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. The valuation of Level 3 investments, when applicable, 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 Company has no Level 3 investments as of September 30, 2021 and December 31, 2020. Management of the Company independently verifies the information provided by pricing services.

Items recorded at fair value by PNM on the Condensed 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)
September 30, 2021
Cash and cash equivalents	$	8,229	$	8,229	$	—
Equity securities:
Corporate stocks, common	99,681		99,681		—
Corporate stocks, preferred	9,046		3,256		5,790
Mutual funds and other	72,494		72,404		90
Available-for-sale debt securities:
U.S. government	44,408		14,914		29,494		$	270
International government	16,925		—		16,925		1,782
Municipals	47,860		—		47,860		1,896
Corporate and other	156,766		—		156,766		14,351
	$	455,409	$	198,484	$	256,925	$	18,299

	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Unrealized Gains
	(In thousands)
December 31, 2020
Cash and cash equivalents	$	6,107	$	6,107	$	—
Equity securities:
Corporate stocks, common	85,271		85,271		—
Corporate stocks, preferred	9,910		3,608		6,302
Mutual funds and other	58,817		58,762		55
Available-for-sale debt securities:
U.S. government	55,839		29,579		26,260		$	950
International government	16,032		—		16,032		2,537
Municipals	50,139		—		50,139		2,779
Corporate and other	158,000		3		157,997		21,121
	$	440,115	$	183,330	$	256,785	$	27,387

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 Condensed Consolidated Balance Sheets, are presented below:

	Carrying Amount		Fair Value
September 30, 2021	(In thousands)
PNMR	$	3,500,233	$	3,724,723
PNM	$	1,732,442	$	1,834,677
TNMP	$	918,074	$	1,040,046
December 31, 2020
PNMR	$	3,295,150	$	3,355,761
PNM	$	1,696,620	$	1,602,547
TNMP	$	853,673	$	1,006,722

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

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Stock-Based Compensation

9 Months Ended

Sep. 30, 2021

Share-based Payment Arrangement [Abstract]

Stock-Based Compensation

Stock-Based Compensation

PNMR has various stock-based compensation programs, including stock options, restricted stock, and performance shares granted under the Performance Equity Plan (“PEP”). Although certain PNM and TNMP employees participate in the PNMR plans, PNM and TNMP do not have separate employee stock-based compensation plans. The Company has not awarded stock options since 2010 and all employee stock options expired or were exercised as of February 2020. Certain restricted stock awards are subject to achieving performance or market targets. Other awards of restricted stock are only subject to time vesting requirements. Additional information concerning stock-based compensation under the PEP is contained in Note 12 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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 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 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. At September 30, 2021, PNMR had unrecognized expense related to stock awards of $5.2 million, which is expected to be recognized over an average of 1.7 years.

PNMR receives a tax deduction for certain stock option exercises during the period the options are exercised, generally for the excess of the price at which the options are sold over the exercise prices of the options, and a tax deduction for the value of restricted stock at the vesting date. All excess tax benefits and deficiencies are recorded to tax expense and classified as operating cash flows when used to reduce income taxes payable. See Note 14.

The grant date fair value for restricted stock and stock awards with internal Company performance targets is determined based on the market price of PNMR 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.

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

	Nine Months Ended September 30,
Restricted Shares and Performance Based Shares	2021			2020
Expected quarterly dividends per share	$	0.3275		$	0.3075
Risk-free interest rate	0.32		%	0.72		%
Market-Based Shares
Dividend yield	2.76		%	2.51		%
Expected volatility	33.69		%	19.41		%
Risk-free interest rate	0.29		%	0.72		%

The following table summarizes activity in restricted stock awards, including performance-based and market-based shares for the nine months ended September 30, 2021:

	Restricted Stock
	Shares	Weighted- Average Grant Date Fair Value
Outstanding at December 31, 2020	168,061	$	40.77
Granted	213,515	43.48
Exercised	(210,572)	40.73
Forfeited	(1,741)	43.72
Outstanding at September 30, 2021	169,263	$	43.71

PNMR’s current stock-based compensation program provides for performance and market targets through 2023. Included in the above table are 124,941 previously awarded shares that were earned for the 2018-2020 performance measurement period and ratified by the Board in February 2021 (based upon achieving market and performance targets at near "maximum" levels). Excluded from the table above are 142,080, 142,047 and 152,414 shares for the three-year performance periods ending in 2021, 2022 and 2023 that will be awarded if all performance and market criteria are achieved at maximum levels and all executives remain eligible.

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

	Nine Months Ended September 30,
Restricted Stock	2021		2020
Weighted-average grant date fair value	$	43.48	$	36.73
Total fair value of restricted shares that vested (in thousands)	$	10,018	$	11,740
Stock Options
Total intrinsic value of options exercised (in thousands)	$	—	$	84

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Financing

9 Months Ended

Sep. 30, 2021

Debt Disclosure [Abstract]

Financing

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 contains a single financial covenant that requires the maintenance of a debt-to-capitalization ratio. For the PNMR 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. Additional information concerning financing activities is contained in Note 7 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

Financing Activities

At December 31, 2020, PNM had $146.0 million of outstanding PCRBs, which have a final maturity of April 1, 2033. These PCRBs were subject to mandatory tender on October 1, 2021 and were successfully remarketed to new investors on that date. The $146.0 million PCRBs bear interest at a fixed rate of 2.15% until their final maturity.

On September 23, 2021, PNM entered into an agreement (the "PNM September 2021 Note Purchase Agreement") with institutional investors for the sale and issuance of $150.0 million aggregate principal amount of two series of Senior Unsecured Notes (the "PNM September 2021 SUNs") to be offered in private placement transactions. The PNM September 2021 SUNs will be issued on or before December 30, 2021. PNM will issue $50.0 million of the PNM September 2021 SUNs at 2.29%, due December 30, 2031, and another $100.0 million at 2.97%, due December 30, 2041. Proceeds from the PNM September 2021 SUNs will be used for funding of capital expenditures, including the purchase of the Western Spirit transmission line, repayment of existing indebtedness, and for general corporate purposes. The PNM September 2021 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 September 2021 SUNs at par. Although there are customary change of control provisions in the PNM debt agreements, the change of control provisions in these agreements, including the PNM September 2021 Note Purchase Agreement, are not triggered by the closing of the Merger. PNM has the right to redeem any or all of the PNM September 2021 SUNs prior to their maturities, subject to payment of a customary make-whole premium.

On July 14, 2021, TNMP entered into an agreement (the "TNMP 2021 Bond Purchase Agreement") with institutional investors for the sale of $65.0 million aggregate principal amount of one series of TNMP first mortgage bonds (the "TNMP 2021 Bonds") offered in private placement transactions. On August 16, 2021, TNMP issued all $65.0 million of the TNMP 2021 Bonds at 2.44% with a maturity of August 15, 2035 and used the proceeds to repay existing debt and for other corporate purposes. The TNMP 2021 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the supplemental indenture governing the TNMP 2021 Bonds. The terms of the supplemental indenture governing the TNMP 2021 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 2021 Bonds at par. However, the definition of change of control in the supplemental indenture governing the TNMP 2021 Bonds will not be triggered by the closing of the Merger. TNMP has the right to redeem any or all of the TNMP 2021 Bonds prior to their maturity, subject to payment of a customary make-whole premium.

On July 14, 2021, PNM entered into an agreement (the "PNM 2021 Note Purchase Agreement") with institutional investors for the sale and issuance of $160.0 million aggregate principal amount of two series of Senior Unsecured Notes (the "PNM 2021 SUNs") offered in private placement transactions. The PNM 2021 SUNs were issued on July 14, 2021. PNM issued $80.0 million of the PNM 2021 SUNs at 2.59%, due July 15, 2033, and another $80.0 million at 3.14%, due July 15, 2041. Proceeds from the PNM 2021 SUNs were used to repay the total amount of $160.0 million of PNM's 5.35% SUNs, at par, earlier than their scheduled maturity of October 1, 2021. The PNM 2021 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 2021 SUNs at par. Although there are customary change of control provisions in the PNM debt agreements, the change of control provisions in these agreements, including the PNM 2021 Note Purchase Agreement, are not triggered by the closing of the Merger. PNM has the right to redeem any or all of the PNM 2021 SUNs prior to their maturities, subject to payment of a customary make-whole premium.

On June 18, 2021, PNM entered into a $75.0 million term loan (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 and for other corporate purposes. The PNM 2021 Term Loan bears interest at a variable rate, which was 0.91% at September 30, 2021 and matures on December 18, 2022.

On May 18, 2021, PNMR entered into a $1.0 billion delayed-draw term loan agreement (the “PNMR 2021 Delayed-Draw Term Loan”), among PNMR, the lenders party thereto, and Wells Fargo Bank, National Association, as administrative agent. Initially PNMR drew $850.0 million to repay and terminate existing indebtedness including the $150.0 million PNMR 2019 Term Loan, the $300.0 million PNMR 2020 Delayed-Draw Term Loan, the $150.0 million PNMR 2020 Term Loan, $92.1 million in borrowings under the PNMR Revolving Credit Facility, the $65.0 million PNMR Development Term Loan, and $40.0 million in borrowings under the PNMR Development Revolving Credit Facility, which was then terminated. Draws on the PNMR 2021 Delayed-Draw Term Loan bear interest at a variable rate, which was 0.94% at September 30, 2021, and mature on May 18, 2023.

The PNMR 2021 Delayed-Draw Term Loan provides that substantially concurrently with the consummation of the transactions set forth in the Merger Agreement, PNMR will assign to Avangrid all of its rights, duties, obligations and liabilities under the PNMR 2021 Delayed-Draw Term Loan and Avangrid will assume from PNMR, as its direct and primary obligation, the payment and performance of all of the duties, liabilities and obligations of PNMR under the PNMR 2021 Delayed-Draw Term Loan pursuant to an amendment and restatement of the PNMR 2021 Delayed-Draw Term Loan in the form of an amended and restated credit agreement attached to the PNMR 2021 Delayed-Draw Term Loan.

On April 24, 2020, TNMP entered into an agreement (the "TNMP 2020 Bond Purchase Agreement") with institutional investors for the sale of $185.0 million aggregate principal amount of four series of TNMP first mortgage bonds (the "TNMP 2020 Bonds") offered in private placement transactions. TNMP issued $110.0 million of TNMP 2020 Bonds on April 24, 2020 and used the proceeds to repay borrowings under the TNMP Revolving Credit Facility and for other corporate purposes. TNMP issued the remaining $75.0 million of TNMP 2020 Bonds on July 15, 2020 and used the proceeds from that issuance to repay borrowings under the TNMP Revolving Credit facility and for other corporate purposes. The TNMP 2020 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the indenture governing the TNMP 2020 Bonds. The terms of the supplemental indenture governing the TNMP 2020 Bonds include the customary covenants discussed above. In the event of a change of control, including the closing of the Merger, TNMP will be required to offer to prepay the TNMP 2020 Bonds at par. TNMP has the right to redeem any or all of the TNMP 2020 Bonds prior to their respective maturities, subject to payment of a customary make-whole premium.

On April 15, 2020, PNM entered into a $250.0 million term loan agreement (the "PNM 2020 Term Loan"), between PNM, the lenders party thereto, and U.S. Bank, as administrative agent. Proceeds from the PNM 2020 Term Loan were used to prepay the PNM 2019 $250.0 million Term Loan due July 2020, without penalty. As discussed below, on April 30, 2020, PNM used $100.0 million of proceeds from the PNM 2020 SUNs to prepay without penalty an equal amount of the PNM 2020 Term Loan. On December 21, 2020, PNM prepaid without penalty the remaining $150.0 million balance of the PNM 2020 Term Loan.

On April 30, 2020, PNM entered into an agreement (the "PNM 2020 Note Purchase Agreement") with institutional investors for the sale of $200.0 million aggregate principal amount of senior unsecured notes offered in private placement transactions. Under the agreement, on April 30, 2020, PNM issued $150.0 million aggregate principal amount of its 3.21% senior unsecured notes, Series A, due April 30, 2030, and $50.0 million of its aggregate principal amount of its 3.57% senior unsecured notes, Series B, due April 29, 2039 (the "PNM 2020 SUNs"). PNM used $100.0 million of proceeds from the PNM 2020 SUNs to repay an equal amount of the PNM 2020 Term Loan. The remaining $100.0 million of the PNM 2020 SUNs

were used to repay borrowings on the PNM Revolving Credit Facility and for other corporate purposes. The PNM 2020 Note Purchase Agreement includes the customary covenants discussed above. Although there are customary change of control provisions in the PNM debt agreements, including the PNM 2020 Note Purchase Agreement, the change of control provisions in these agreements are not triggered by the closing of the Merger. PNM has the right to redeem any or all of the PNM 2020 SUNs prior to their maturities, subject to payment of a customary make-whole premium.

At December 31, 2019, PNM had $40.0 million of outstanding PCRBs, which have a final maturity of June 1, 2040 and two series of outstanding PCRBs of $39.3 million and $21.0 million, which have a final maturity of June 1, 2043. These PCRBs, aggregating $100.3 million, were subject to mandatory tender on June 1, 2020. On June 1, 2020, PNM purchased these PCRBs utilizing borrowings under the PNM Revolving Credit Facility and converted the PCRBs to the weekly mode. PNM held these PCRBs (without legally canceling them) until July 1, 2020, when they were remarketed in the weekly mode (the "PNM Floating Rate PCRBs") and PNM used the remarketing proceeds to repay the revolver borrowings. PNM Floating Rate PCRBs in the weekly mode bore interest at rates that were reset weekly, giving investors the option to return the PCRBs for remarketing to new investors upon 7 days' notice. At September 30, 2021, this rate was 0.11%. A corresponding portion of the borrowing capacity under the PNM Revolving Credit Facility was reserved to support the investors' option to return the PNM Floating Rate PCRBs upon 7 days' notice. On October 1, 2021 PNM converted the PNM Floating Rate PCRBs to a fixed rate period and successfully remarketed them to new investors ("PNM 2021 Fixed Rate PCRBs"). The PNM 2021 Fixed Rate PCRBs now bear interest at 0.875% and are subject to mandatory tender on October 1, 2026.

At June 30, 2020 and December 31, 2019, PNM had PCRBs outstanding of $36.0 million at 6.25% issued by the Maricopa County, Arizona Pollution Control Corporation as well as $255.0 million at 5.90% and $11.5 million at 6.25% issued by the City of Farmington, New Mexico. The $36.0 million PCRBs became callable at 101% of par on January 1, 2020 and the remaining $266.5 million PCRBs became callable at par on June 1, 2020. On June 22, 2020, PNM provided notice to the bondholders that it was calling the PCRBs aggregating $302.5 million. On July 22, 2020, PNM purchased the PCRBs in lieu of redemption and remarketed them to new investors (the "PNM 2020 Fixed Rate PCRBs"). Information concerning the funding dates, mandatory tender dates, and interest rates on the PNM 2020 Fixed Rate PCRBs can be found in Note 7 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

In August 2020, PNMR entered into letter of credit arrangements with Wells Fargo Bank, N.A. (the "WFB LOC Facility") under which letters of credit aggregating $30.3 million were issued to facilitate the posting of reclamation bonds currently held by WSJ LLC (who assumed all the obligations of SJCC post-bankruptcy). The reclamation bonds were required to be posted in connection with permits relating to the operation of the San Juan mine.

On March 9, 2018, PNMR issued $300.0 million aggregate principal amount of 3.25% SUNs (the “PNMR 2018 SUNs”), which were set to mature on March 9, 2021. On December 22, 2020, PNMR entered into the $300.0 million PNMR 2020 Delayed-Draw Term Loan that would have matured in January 2022 and drew $80.0 million to refinance existing indebtedness and for other corporate purposes. On March 9, 2021, PNMR utilized the remaining $220.0 million of capacity under the PNMR 2020 Delayed-Draw Term Loan to repay an equivalent amount of the PNMR 2018 SUNs. The remaining $80.0 million repayment of the PNMR 2018 SUNs was funded through borrowings under the PNMR Revolving Credit Facility.

On October 20, 2020, the execution of the Merger Agreement constituted a “Change of Control” under certain PNMR, TNMP, and PNMR Development debt agreements. Under each of the specified debt agreements, a “Change of Control” constitutes an “Event of Default,” pursuant to which the lender parties thereto have the right to accelerate the indebtedness under the debt agreements. The definition of Change of Control under the PNM debt agreements and PNM note purchase agreements was not triggered by the execution of the Merger Agreement.

On October 26, 2020, PNMR, TNMP and PNMR Development entered into amendment agreements with the lender parties thereto to amend the definition of "Change of Control" such that the entry into the Merger Agreement would not constitute a Change of Control and to waive the Event of Default arising from entry into the Merger Agreement. On September 15, 2021, PNMR and TNMP entered into amendment agreements with the lender parties thereto to further amend the definition of "Change of Control" such that the closing of the Merger does not constitute a Change of Control. The Change of Control provisions in the PNM debt agreements, PNM note purchase agreements, and TNMP 2021 Bond Purchase Agreement are not triggered by the closing of the Merger and did not require amendment.

The documents governing TNMP's aggregate $750.0 million of outstanding 2014 to 2020 First Mortgage Bonds ("TNMP FMBs") obligated TNMP to offer, within 30 business days following the signing of the Merger Agreement, to prepay all $750.0 million outstanding TNMP FMBs at 100% of the principal amount, plus accrued and unpaid interest thereon, but without any make-whole amount or other premium. TNMP made such offer to prepay the TNMP FMBs in accordance with the

terms of the TNMP FMBs, and none of the holders of the TNMP FMBs accepted TNMP’s offer. The documents governing the 2014 to 2020 TNMP FMBs require TNMP to make another offer, within 30 business days of closing of the Merger, to prepay all $750.0 million outstanding TNMP FMBs at par. TNMP will make such offer to prepay all $750.0 million outstanding TNMP FMBs in accordance with the terms of the TNMP FMBs; however, holders of the TNMP FMBs are not required to tender their TNMP FMBs and may accept or reject such offer to prepay. As discussed above, the supplemental indenture that governs the TNMP 2021 Bonds excludes the Merger from the definition of Change of Control.

The TNMP FMBs are not registered under the Securities Act and may not be offered or sold in the United States absent registration or applicable exemption from registration requirements and applicable state laws. The information in this Quarterly Report on Form 10-Q is for informational purposes only and is neither an offer to purchase, nor a solicitation of an offer to sell, subscribe for or buy any securities in any jurisdiction pursuant to the proposed transactions or otherwise, nor shall there be any sale, issuance or transfer of securities in any jurisdiction in contravention of applicable law. Similar to the offer to prepay made after signing the Merger Agreement, the post-Merger closing offer to prepay the TNMP FMBs will be made only pursuant to an offer to prepay, which will set forth the terms and conditions of the offer to prepay.

At September 30, 2021, variable interest rates were 0.94% on the PNMR 2021 Delayed-Draw Term Loan that matures in May 2023, 0.91% on the PNM 2021 Term Loan that matures in December 2022, and 0.11% on the PNM Floating Rate PCRBs in the weekly mode.

Short-term Debt and Liquidity

Currently, the PNMR Revolving Credit Facility has a financing capacity of $300.0 million and the PNM Revolving Credit Facility has a financing capacity of $400.0 million. Both facilities currently expire on October 31, 2023 and contain options to be extended through October 2024, subject to approval by a majority of the lenders. PNM also has the $40.0 million PNM 2017 New Mexico Credit Facility that expires on December 12, 2022. The TNMP Revolving Credit Facility is a $75.0 million revolving credit facility secured by $75.0 million aggregate principal amount of TNMP first mortgage bonds that matures on September 23, 2022 and contains two one-year extension options, subject to approval by a majority of the lenders. PNMR Development had a $40.0 million revolving credit facility that was set to expire on January 31, 2022. As discussed above, on May 18, 2021, the PNMR Development Revolving Credit Facility was terminated. Variable interest rates under these facilities are based on LIBOR but contain provisions which allow for the replacement of LIBOR with other widely accepted interest rates.

Short-term debt outstanding consists of:

	September 30,		December 31,
Short-term Debt	2021		2020
	(In thousands)
PNM:
PNM 2017 New Mexico Credit Facility	$	—	$	10,000
PNMR:
PNMR Revolving Credit Facility	13,900		12,000
PNMR Development Revolving Credit Facility	—		10,000
	$	13,900	$	32,000

At September 30, 2021, the weighted average interest rate was 1.58% for the PNMR Revolving Credit Facility. There were no borrowings outstanding under the PNM Revolving Credit Facility, the PNM 2017 New Mexico Revolving Credit Facility, or the TNMP Revolving Credit Facility at September 30, 2021.

In addition to the above borrowings, PNMR, PNM, and TNMP had letters of credit outstanding of $3.4 million, $2.2 million, and zero at September 30, 2021 that reduce the available capacity under their respective revolving credit facilities. The above table excludes intercompany debt. As of September 30, 2021 and December 31, 2020, neither PNM nor TNMP had any intercompany borrowings from PNMR. PNMR Development had $0.1 million and $0.3 million in intercompany borrowings from PNMR at September 30, 2021 and December 31, 2020. PNMR had no intercompany borrowings from PNM, TNMP, or PNMR Development at either of September 30, 2021 or December 31, 2020.

In 2017, PNMR entered into three separate four-year hedging agreements whereby it effectively established fixed interest rates of 1.926%, 1.823%, and 1.629%, plus customary spreads over LIBOR for three separate tranches, each of $50.0 million, of its variable rate debt. On March 23, 2021 the 1.926% fixed interest rate hedge agreement expired according to its terms and the remaining agreements expired on May 23, 2021.

At October 22, 2021, PNMR, PNM, and TNMP had availability of $286.0 million, $397.8 million, and $75.0 million under their respective revolving credit facilities, including reductions of availability due to outstanding letters of credit. PNM also had $40.0 million of availability under the PNM 2017 New Mexico Credit Facility. Total availability at October 22, 2021, on a consolidated basis, was $798.8 million for PNMR. As of October 22, 2021, PNM and TNMP had no borrowings from PNMR under their intercompany loan agreements however, PNMR Development had $0.2 million in borrowings from PNMR. PNMR had no borrowings from PNM, TNMP, or PNMR Development. At October 22, 2021, PNMR, PNM, and TNMP had invested cash of $0.9 million, $61.8 million, and $11.4 million.

The Company’s debt arrangements have various maturities and expiration dates. PNM has $104.5 million of PCRBs that must be repriced in June 2022. Additional information on debt maturities is contained in Note 7 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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Pension and Other Postretirement Benefit Plans

9 Months Ended

Sep. 30, 2021

Retirement Benefits [Abstract]

Pension and Other Postretirement Benefit Plans

Pension and Other Postretirement Benefit Plans

PNMR 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”). PNMR 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. The Company presents the service cost component of its net periodic benefit costs in administrative and general expenses and the non-service costs components in other income (deductions), net of amounts capitalized or deferred to regulatory assets and liabilities, on the Condensed Consolidated Statements of Earnings. PNM and TNMP receive a regulated return on the amounts funded for pension and OPEB plans in excess of accumulated periodic cost or income to the extent included in retail rates (a “prepaid pension asset”).

Additional information concerning pension and OPEB plans is contained in Note 11 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K. Annual net periodic benefit cost for the plans is actuarially determined using the methods and assumptions set forth in that note and is recognized ratably throughout the year. Differences between TNMP's annual net periodic costs (income) and amounts included in its regulated rates are deferred to regulatory assets or liabilities, for recovery or refund in future rate proceedings.

PNM Plans

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

	Three Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	5	$	9	$	—	$	—
Interest cost	4,036		4,985		476		613		90		123
Expected return on plan assets	(7,133)		(7,363)		(1,042)		(1,387)		—		—
Amortization of net loss	4,541		4,465		—		87		99		101
Amortization of prior service cost	—		(138)				—		—		—
Net Periodic Benefit Cost (Income)	$	1,444	$	1,949	$	(561)	$	(678)	$	189	$	224

	Nine Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	18	$	29	$	—	$	—
Interest cost	12,107		14,956		1,430		1,840		271		367
Expected return on plan assets	(21,398)		(22,089)		(3,125)		(4,161)		—		—
Amortization of net loss	13,624		13,395		—		261		296		302
Amortization of prior service cost	—		(415)		—		—		—		—
Net Periodic Benefit Cost (Income)	$	4,333	$	5,847	$	(1,677)	$	(2,031)	$	567	$	669

PNM did not make any contributions to its pension plan trust in the nine months ended September 30, 2021 and 2020 and does not anticipate making any contributions to the pension plan in 2021 through 2026 based on current law, funding requirements, and estimates of portfolio performance. Funding assumptions were developed using a discount rate of 2.9%. Actual amounts to be funded in the future will be dependent on the actuarial assumptions at that time, including the appropriate discount rate. PNM may make additional contributions at its discretion. PNM did not make any cash contributions to the OPEB trust in the nine months ended September 30, 2021 and 2020, however, a portion of the disbursements attributable to the OPEB trust are paid by PNM and are therefore considered to be contributions to the OPEB plan. Payments by PNM on behalf of the PNM OPEB plan were $1.0 million and $2.7 million for the three and nine months ended September 30, 2021 and $1.0 million and $3.1 million in the three and nine months ended September 30, 2020. These payments are expected to total $3.4 million in 2021 and $15.1 million for 2022-2026. Disbursements under the executive retirement program, which are funded by PNM and considered to be contributions to the plan, were $0.3 million and $1.1 million in the three and nine months ended September 30, 2021 and $0.3 million and $1.1 million for the three and nine months ended September 30, 2020 and are expected to total $1.3 million during 2021 and $6.0 million for 2022-2026.

TNMP Plans

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

	Three Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	12	$	12	$	—	$	—
Interest cost	435		545		77		93		4		6
Expected return on plan assets	(795)		(821)		(101)		(136)		—		—
Amortization of net (gain) loss	311		315		(81)		(81)		8		6
Amortization of prior service cost	—		—		—		—		—		—
Net Periodic Benefit Cost (Income)	$	(49)	$	39	$	(93)	$	(112)	$	12	$	12

	Nine Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	34	$	35	$	—	$	—
Interest cost	1,306		1,633		231		280		13		17
Expected return on plan assets	(2,386)		(2,463)		(304)		(404)		—		—
Amortization of net (gain) loss	935		944		(242)		(243)		25		18
Amortization of prior service cost	—		—		—		—		—		—
Net Periodic Benefit Cost (Income)	$	(145)	$	114	$	(281)	$	(332)	$	38	$	35

TNMP did not make any contributions to its pension plan trust in the nine months ended September 30, 2021 and 2020 and does not anticipate making any contributions to the pension plan in 2021 through 2026 based on current law, funding requirements, and estimates of portfolio performance. Funding assumptions were developed using a discount rate of 2.9%. Actual amounts to be funded in the future will depend on the actuarial assumptions at that time, including the appropriate discount rate. TNMP may make additional contributions at its discretion. TNMP did not make any contributions to the OPEB trust in the three and nine months ended September 30, 2021 and 2020 and does not expect to make contributions to the OPEB trust during the period 2021-2026. Disbursements under the executive retirement program, which are funded by TNMP and considered to be contributions to the plan, were zero in the three and nine months ended September 30, 2021 and 2020 and are expected to total $0.1 million during 2021 and $0.4 million in 2022-2026.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2021

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

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 12. 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 estimable. 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, and commitments will have a material effect on its financial condition, results of operations, or cash flows.

Additional information concerning commitments and contingencies is contained in Note 16 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

Commitments and Contingencies Related to the Environment

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. In August 2014, APS and the DOE entered into a settlement agreement that establishes a process for the payment of claims for costs incurred through December 31, 2019. In July 2020, APS accepted the DOE's extension of the settlement agreement for recovery of costs incurred through December 31, 2022. 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 to the extent applicable to NMPRC regulated operations.

PNM estimates that it will incur approximately $59.6 million (in 2019 dollars) for its share of the costs related to the on-site interim storage of spent nuclear fuel at PVNGS during the term of the operating licenses. PNM accrues these costs as a component of fuel expense as the nuclear fuel is consumed. At September 30, 2021 and December 31, 2020, PNM had a liability for interim storage costs of $13.0 million and $12.8 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

In 2019, the Governor signed into New Mexico state law Senate Bill 489, known as the Energy Transition Act (“ETA”). The ETA became effective as of June 14, 2019 and 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 amends the REA and 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 amends sections of the REA to allow 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. The ETA also directs the New Mexico Environmental Improvement Board to adopt standards of performance that limit CO2 emissions to no more than 1,100 lbs. per MWh beginning January 1, 2023 for new or 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 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.

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 will have a significant impact on PNM’s future generation portfolio, including PNM’s planned retirement of SJGS in 2022 and the planned Four Corners exit in 2024. PNM cannot predict the full impact of the ETA or the outcome of its pending and potential future generating resource abandonment and replacement resource filings with the NMPRC. See additional discussion in Note 12 of PNM’s SJGS and Four Corners Abandonment Applications.

The Clean Air Act

Regional Haze

In 1999, EPA developed a regional haze program and regional haze rules under the CAA. The rule directs each of the 50 states to address 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. If it was demonstrated that the emissions from these sources caused or contributed to visibility impairment in any Class I area, BART must have been installed by the beginning of 2018. 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.

In 2017, EPA published revisions to the regional haze rule in the Federal Register. EPA also provided a companion draft guidance document for public comment. The new rule delayed the due date for the next cycle of SIPs from 2019 to 2021, altered the planning process that states must employ in determining whether to impose “reasonable progress” emission reduction measures, and gave new authority to federal land managers to seek additional emission reduction measures outside of the states’ planning process. Finally, the rule made several procedural changes to the regional haze program, including changes to the schedule and process for states to file 5-year progress reports. EPA’s new rule was challenged by numerous parties. On January 19, 2018, EPA filed a motion to hold the case in abeyance in light of several letters issued by EPA on January 17, 2018 to grant various petitions for reconsideration of the 2017 rule revisions. EPA’s decision to revisit the 2017 rule is not a determination on the merits of the issues raised in the petitions.

On December 20, 2018, EPA released a new guidance document on tracking visibility progress for the second planning period. EPA is allowing states discretion to develop SIPs that may differ from EPA’s guidance as long as they are consistent with the CAA and other applicable regulations. On August 20, 2019, EPA finalized the draft guidance that was released in 2016 as a companion to the regional haze rule revisions, and EPA clarified that guidance in a memorandum issued on July 8, 2021. SIPs for the second planning period were due in July 2021. 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 will retire its share of SJGS in 2022. NMED's current timeline indicates the SIP will be submitted between September 2021 and January 2022. PNM cannot predict the outcome of these matters with respect to Four Corners.

Carbon Dioxide Emissions

On August 3, 2015, EPA established standards to limit CO2 emissions from power plants. EPA took three separate but related actions in which it: (1) established the Carbon Pollution Standards for new, modified, and reconstructed power plants; (2) established the Clean Power Plan to set standards for carbon emission reductions from existing power plants; and (3) released a proposed federal plan associated with the final Clean Power Plan. The Clean Power Plan was published on October 23, 2015.

Multiple states, utilities, and trade groups filed petitions for review in the DC Circuit to challenge both the Carbon Pollution Standards for new sources and the Clean Power Plan for existing sources. Challengers successfully petitioned the US Supreme Court for a stay of the Clean Power Plan. However, before the DC Circuit could issue an opinion regarding either the Carbon Pollution Standards or the Clean Power Plan, the Trump Administration asked that the case be held in abeyance while the rule was being re-evaluated, which was granted.

On June 19, 2019, EPA repealed the Clean Power Plan, promulgated the ACE Rule, and revised the implementing regulations for all emission guidelines. EPA set the Best System of Emissions Reduction ("BSER") for existing coal-fired power plants as heat rate efficiency improvements based on a range of "candidate technologies" that can be applied inside the fence-line. Rather than setting a specific numerical standard of performance, EPA's rule directed states to determine which of the candidate technologies to apply to each coal-fired unit and establish standards of performance based on the degree of emission reduction achievable based on the application of BSER. On September 17, 2019, the DC Circuit issued an order that granted motions by various petitioners, including industry groups and EPA, to dismiss the cases challenging the Clean Power Plan as moot due to EPA’s issuance of the ACE Rule.

However, on January 19, 2021, the DC Circuit issued an opinion in American Lung Association and American Public Health Association v. EPA, et al. regarding challenges to the ACE Rule. The DC Circuit vacated the ACE Rule and remanded the record back to the EPA for further consideration consistent with its opinion, finding that EPA misinterpreted the CAA when it determined that the language of section 111 unambiguously barred consideration of emissions reductions options that were not applied at the source. Four petitions for writ of certiorari were filed in the U.S. Supreme Court seeking review of the DC Circuit’s January opinion vacating EPA’s repeal and replacement of the Obama Administration’s Clean Power Plan regulations for controlling carbon emissions from existing power plants. The petitioners include 1) West Virginia and 18 other states that had intervened to defend the ACE Rule, 2) North American Coal Corporation, 3) North Dakota (separately from the other states), and 4) Westmoreland Mining Holdings LLC. Several briefs were filed in support of the certiorari petitions. After receiving an extension from the DC Circuit, EPA filed its response on August 5, 2021. Briefing was completed on August 24, 2021 on the four petitions for writ.

While the DC Circuit did not uphold the ACE Rule, it did not reinstate the Clean Power Plan. EPA filed a motion seeking a partial stay of the mandate as to the repeal of the Clean Power Plan, to ensure the court’s order will not render effective the now out-of-date Clean Power Plan. On February 22, 2021, the U.S. Court of Appeals for the DC Circuit granted EPA’s motion, indicating that it would withhold issuance of the mandate with respect to the repeal of the Clean Power Plan until EPA responds to the court’s remand in a new rulemaking action. 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 the Biden Administration is unlikely to finalize the revisions proposed in 2018 and that reconsideration of the rule has concluded.

While corresponding NSR reform regulations were proposed as part of the proposed ACE Rule, the final rule did not include such reform measures. Unrelated to the ACE Rule, EPA issued a proposed rule on August 1, 2019, to clarify one aspect of the pre-construction review process for evaluating whether the NSR permitting program would apply to a proposed project at an existing source of emissions. The final rule on NSR Project Emissions Accounting became effective on December 24, 2020, clarifying that both emissions increases and decreases resulting from a project are to be considered in determining whether the proposed project will result in an increase in air emissions. The Biden Administration denied a petition for reconsideration of the rule on October 12, 2021, but indicated that it plans to initiate a new rulemaking to address the issues raised by the petitioners.

On January 27, 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.

PNM’s review of the GHG emission reductions standards that may occur as a result of legislation or regulation under the Biden Administration and in response to the court's ruling on the ACE Rule is ongoing. PNM cannot predict the impact these standards may have on its operations or a range of the potential costs of compliance, if any.

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 – On April 18, 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.

SO2 Standard – On May 13, 2014, EPA released the draft data requirements rule for the 1-hour SO2 NAAQS, which directs state and tribal air agencies to characterize current air quality in areas with large SO2 sources to identify maximum 1-hour SO2 concentrations. This characterization requires areas be designated as attainment, nonattainment, or unclassifiable for compliance with the 1-hour SO2 NAAQS. 

On August 11, 2015, EPA released the Data Requirements Rule for SO2, telling states how to model or monitor to determine attainment or nonattainment with the new 1-hour SO2 NAAQS.  NMED submitted the first annual report for SJGS as required by the Data Requirements Rule in June 2018. That report recommended that no further modeling was warranted due to decreased SO2 emissions. NMED submitted the second and third annual modeling report to EPA in July 2019 and July 2020. Those reports retained the recommendation that no further modeling is needed at this time and are subject to EPA review.

On February 25, 2019, EPA announced its final decision to retain, without changes, the primary health-based NAAQS for SO2. Specifically, EPA will retain 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.

On March 26, 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. This is EPA’s fourth and final set of actions to designate areas of the U.S. for the 2010 SO2 NAAQS. All areas of New Mexico have been designated attainment/unclassifiable through four rounds of designations by the EPA.

Ozone Standard – On October 1, 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. On July 13, 2020, EPA proposed to retain the existing ozone NAAQS based on a review of the full body of currently available scientific evidence and exposure/risk information. EPA finalized its decision to retain the ozone NAAQS in a notice published on December 31, 2020 making it immediately effective. The Center for Biological Diversity filed a lawsuit on February 25, 2021, challenging the decision to retain the existing ozone standard, and the Biden Administration has included the decision in its list of actions that may be reconsidered.

On November 10, 2015, EPA proposed a rule revising its Exceptional Events Rule, which outlines the requirements for excluding air quality data (including ozone data) from regulatory decisions if the data is affected by events outside an area’s control. The proposed rule is important in light of the more stringent ozone NAAQS final rule since western states like New Mexico and Arizona are subject to elevated background ozone transport from natural local sources, such as wildfires and stratospheric inversions, and transported via winds from distant sources in other regions or countries. EPA finalized the rule on October 3, 2016 and released related guidance in 2018 and 2019 to help implement its new exceptional events policy.

During 2017 and 2018, EPA released rules establishing area designations for ozone. In those rules, San Juan County, New Mexico, where SJGS and Four Corners are 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 is located in Doña Ana County, it is not located within the small area designated as non-attainment for the 2015 ozone standard. The rule became effective May 8, 2018.

On November 22, 2019, EPA issued findings that several states, including New Mexico, had failed to submit interstate transport SIPs for the 2015 8-hour ozone NAAQS. In response, in December 2019, NMED published the Public Review Draft of the New Mexico 2013 NAAQS Good Neighbor SIP that demonstrates that there are no significant contributions from New Mexico to downwind problems in meeting the federal ozone standard.

NMED has responsibility for bringing the small area in Doña Ana County designated as marginal/non-attainment for ozone into compliance and will look at all sources of NOx and volatile organic compounds. NMED has submitted the required elements for the Sunland Park Ozone Nonattainment Area SIP. This includes a transportation conformity demonstration, a 2017 baseline emissions inventory and emissions statement, and an amendment to the state's Nonattainment Permitting rules at 20.2.79 New Mexico Administrative Code to conform to EPA's SIP Requirements Rule for 2015 Q3 NAAQS (i.e., "implementation rule").

The SIP elements had staggered deadlines and were done in three submissions; 1) the transportation conformity demonstration was completed by the El Paso Metropolitan Planning Organization on behalf of New Mexico in 2019, which is responsible for transportation planning in that area. The submission received concurrence from EPA and the Federal Highway Administration; 2) the emissions inventory and statement SIP was submitted to EPA in September 2020; and 3) the Nonattainment New Source Review SIP was submitted to EPA on August 10, 2021.

PNM does not believe there will be material impacts to its facilities because of NMED’s 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. PNM cannot predict the outcome of this matter.

PM Standard – On January 30, 2020, EPA published in the Federal Register a notice announcing the availability of a final Policy Assessment for the Review of the NAAQS for Particulate Matter (the "Final PA"). The final assessment was prepared as part of the review of the primary and secondary PM NAAQS. In the assessment, EPA recommended lowering the primary annual PM2.5 standard to between 8 µg/m3 and 10 µg/m3. However, on April 30, 2020, EPA published a proposed rule to retain the current standards for PM due to uncertainties in the data relied upon in the Final PA. EPA accepted comments on the proposed rule through June 29, 2020. On December 7, 2020, EPA announced it will retain, without revision, the existing primary (health-based) and secondary (welfare-based) NAAQS for PM, and EPA published a notice of that final action on December 18, 2020, making it immediately effective. On January 14, 2021, several states and New York City filed a petition for review in the DC Circuit, challenging EPA’s final rule retaining the current primary and secondary PM NAAQS. On February 9, 2021, a similar lawsuit was filed by the Center for Biological Diversity in the DC Circuit. On June 10, 2021, EPA announced that it will reconsider the previous administration’s December 2020 decision to retain the current primary and secondary PM NAAQS and on October 8, 2021, EPA announced the release of a new draft policy assessment (the "Draft PA"). Like the Final PA, the Draft PA states that available scientific evidence and technical information indicate that the current standards may not be adequate to protect public health and welfare, as required by the Clean Air Act. EPA anticipates issuing a proposed rule in summer 2022 and a final rule in spring 2023.

Navajo Nation Environmental Issues

Four Corners is located on the Navajo Nation and is held under easements granted by the federal government, as well as agreements with the Navajo Nation which grant each of the owners the right to operate on the site. The Navajo Acts purport to give the Navajo Nation Environmental Protection Agency authority to promulgate regulations covering air quality, drinking water, and pesticide activities, including those activities that occur at Four Corners. In October 1995, the Four Corners participants filed a lawsuit in the District Court of the Navajo Nation challenging the applicability of the Navajo Acts to Four Corners. In May 2005, APS and the Navajo Nation signed an agreement resolving the dispute regarding the Navajo Nation’s authority to adopt operating permit regulations under the Navajo Nation Air Pollution Prevention and Control Act. As a result of this agreement, APS sought, and the court granted, dismissal of the pending litigation in the Navajo Nation Supreme Court and the Navajo Nation District Court, to the extent the claims relate to the CAA. The agreement does not address or resolve any dispute relating to other aspects of the Navajo Acts. PNM cannot currently predict the outcome of these matters or the range of their potential impacts.

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 SJGS and Four Corners, seven options for meeting Best Technology Available (“BTA”) standards for reducing impingement. SJGS has a closed-cycle recirculating cooling system, which is a listed BTA and may also qualify for the “de minimis rate of impingement” based on the design of the intake structure. 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 determination. Compliance deadlines under the rule are tied to permit renewal and will be subject to a schedule of compliance established by the permitting authority.

The rule is not clear as to how it applies and what the compliance timelines are for facilities like SJGS that have a cooling water intake structure and only a multi-sector general stormwater permit. However, EPA has indicated that it is contemplating a December 31, 2023 compliance deadline. PNM is working with EPA regarding this issue and does not expect material changes as a result of any requirements that may be imposed upon SJGS, particularly given the NMPRC's April 1, 2020 approval for PNM to retire its share of SJGS by June 2022.

On May 23, 2018, several environmental groups sued EPA Region IX in the United States Court of Appeals for the Ninth Circuit Court 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 on June 12, 2018. The permit did not contain conditions related to the cooling water intake structure rule as EPA determined that the facility has achieved BTA for both impingement and entrainment by operating a closed-cycle recirculation system. On July 16, 2018, 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 several requirements under the Clean Water Act and did not contain required provisions concerning certain revised effluent limitation guidelines, existing-source regulations governing cooling-water intake structures, and effluent limits for surface seepage and subsurface discharges from coal-ash disposal facilities. On December 19, 2018, EPA withdrew the Four Corners NPDES permit in order to examine issues raised by the environmental groups. Withdrawal of the permit moots the appeal pending before the EAB. EAB thereafter dismissed the environmental groups’ appeal. EPA issued an updated NPDES permit on September 30, 2019. The permit was once again appealed to the EAB and was stayed before the effective date. Oral argument was heard on September 3, 2020. The EAB issued an order denying the petition for review on September 30, 2020. The denial was based on the EAB's determination that the petitioners had failed to demonstrate that review of the permit was warranted on any of the grounds presented in the petition. 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 and will expire on November 30, 2025. 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 Circuit. The September 2019 permit remains in effect pending this appeal. PNM cannot predict whether there will be further appeals of this matter or whether the outcome of any such appeal will have a material impact on PNM’s financial position, results of operations or cash flows.

Effluent Limitation Guidelines

On June 7, 2013, EPA published proposed revised wastewater effluent limitation guidelines establishing technology-based wastewater discharge limitations for fossil fuel-fired electric power plants.  EPA signed the final Steam Electric Effluent Limitation Guidelines rule on September 30, 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 Effluent Limitation Guidelines rule was challenged in the U.S. Court of Appeals for the Fifth Circuit by numerous parties. On April 12, 2017, EPA signed a notice indicating its intent to reconsider portions of the rule, and on August 22, 2017, 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. On April 12, 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.

On September 18, 2017, EPA published a final rule for postponement of certain compliance dates. The rule postponed the earliest date on which compliance with the Effluent Limitation Guidelines for these waste streams would be required from November 1, 2018 until November 1, 2020. On November 22, 2019, EPA published a proposed rule revising the original Effluent Limitation Guidelines while maintaining the compliance dates. Comments were due January 21, 2020. On October 13, 2020, EPA published in the Federal Register the final Steam Electric Effluent Limitation Guidelines 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 rule will require compliance with new limits as soon as possible on or after October 13, 2021, but no later than December 31, 2025.

Because SJGS is zero discharge for wastewater and is not required to hold a NPDES permit, it is expected that minimal to no requirements will be imposed. Reeves Station discharges cooling tower blowdown to a publicly owned treatment plant and holds an NPDES permit. It is expected that minimal to no requirements will be imposed at Reeves Station.

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 in 2023. 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 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 December 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 March 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 in October 2019. 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.

PNM submitted work plans to NMED in January 2021 for review and approval. PNM is prepared to commence work shortly after receiving NMED approval.

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 are currently disposed of in the surface mine pits adjacent to the plant. SJGS does not operate any 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 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 final coal ash rule, which became effective on October 19, 2015, included a non-hazardous waste determination for coal ash and sets minimum criteria for existing and new CCR landfills and surface impoundments. On December 16, 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 contains a number of provisions related to the CCR rules. Among other things, the WIIN Act allows, but does not require, states to develop and submit CCR permit programs for EPA approval, provides flexibility for states to incorporate EPA’s final rule for CCRs or develop other criteria that are at least as protective as EPA’s final rule, and requires 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 will implement the permit program in states that choose not to implement a program, subject to Congressional funding. Until permit programs are in effect, EPA has authority to directly enforce the CCR rule. 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. There is no timeline for establishing either state or federal permitting programs.

On July 30, 2018, EPA published a rule that constitutes “Phase One, Part One” of its ongoing reconsideration and revision of the April 17, 2015 CCR rule. The final Phase One, Part One rule includes two types of revisions. The first revision 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. This deadline was again 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.

On August 14, 2019, EPA published a second round of revisions, which are commonly referred to as the “Phase Two” revisions. Phase Two proposed revisions to reporting and accessibility to public information, the "CCR piles" and "beneficial use" definitions and the requirements for management of CCR piles. EPA has reopened and extended the Phase Two comment several times. Most recently, on March 12, 2021, EPA reopened the comment period on its prior notice that announced the availability of new information and data pertaining to the Phase Two proposed rule. EPA extended the comment period for an additional 60 days, until May 11, 2021. EPA has not yet finalized provisions in Phase Two related to beneficial use of CCR and CCR piles. It is anticipated EPA will issue proposed and final rules addressing these issues in 2022.

Since promulgating its Phase Two proposal, EPA has finalized two other rules addressing various CCR rule provisions. On December 2, 2019, 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 CCR Rule, Part A also proposed changing the classification of compacted soil-lined or clay-lined surface impoundments from “lined” to “unlined”. In addition, Part A delineated a process for owners/operators to submit requests for alternative closure deadlines based on lack of alternate disposal capacity. EPA issued the final Part A on August 28, 2020, which became effective on September 28, 2020. This rule finalized the classification of soil-lined and clay-lined surface impoundments as unlined, thus, triggering closure or retrofit requirements for those impoundments. The final Part A also gave operators of unlined impoundments until April 11, 2021 to cease receipt of waste at these units and initiate closure.

On March 3, 2020, EPA issued the proposed Holistic Approach to Closure Part B ("Part B"), which delineated the process for owners/operators to submit alternate liner demonstrations for clay-lined surface impoundments that could otherwise meet applicable requirements. Part B also proposed regulations addressing beneficial use for closure of surface impoundments. On November 12, 2020, EPA issued the final Part B rule, which became effective December 14, 2020. This rule did not include beneficial use of CCR for closure, which EPA explains will be addressed in subsequent rulemaking actions. EPA intends to issue several other rulemakings covering legacy ponds and finalizing parts of previously proposed rules. These proposed rules and final rules are expected in 2022.

On February 20, 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. The deadline to provide comments was extended to August 7, 2020. The final rule is expected in January 2022. PNM cannot predict the outcome of EPA’s rule making activity or the outcome of any related litigation, and whether or how such a ruling would affect operations at Four Corners.

The CCR rule does not cover mine placement of coal ash. OSM is expected to publish a proposed rule covering mine placement in the future and will likely be influenced by EPA’s rule and the determination by EPA that CCRs are non-hazardous. 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. Based upon the requirements of the final Part A CCR rule, PNM conducted a CCR assessment at SJGS and made minor modifications at the plant to ensure that there are no facilities that would be considered impoundments or landfills under the rule. 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 will need corrective action or will need to cease operations and initiate closure by April 11, 2021. As part of this assessment, Four Corners will continue to gather additional groundwater data and perform remedial evaluations. 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

SJGS

The coal requirements for SJGS are supplied by WSJ LLC. In addition to coal delivered to meet the current needs of SJGS, PNM has prepaid the current San Juan mine owner and operator, WSJ LLC, for certain coal mined but not yet delivered to the plant site. At September 30, 2021 and December 31, 2020, prepayments for coal, which are included in other current assets, amounted to $21.9 million and $26.3 million. Additional information concerning the coal supply for SJGS is contained in Note 16 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

In conjunction with the activities undertaken to comply with the CAA for SJGS, PNM and the other owners of SJGS evaluated alternatives for the supply of coal to SJGS. On July 1, 2015, PNM and Westmoreland entered into a new coal supply agreement (the “SJGS CSA”), pursuant to which Westmoreland, through its indirectly wholly-owned subsidiary SJCC, agreed to supply all of the coal requirements of SJGS through June 30, 2022. PNM and Westmoreland also entered into agreements under which CCR disposal and mine reclamation services for SJGS would be provided. As discussed in Note 6, WSJ LLC assumed the rights and obligations of SJCC under the SJGS CSA and the agreements for CCR disposal and mine reclamation services.

Pricing under the SJGS CSA is primarily fixed, with adjustments to reflect changes in general inflation. The pricing structure takes into account that WSJ LLC has been paid for coal mined but not delivered. PNM has provided notice to Westmoreland that PNM does not intend to extend the term of the SJGS CSA or to negotiate a new coal supply agreement for SJGS, which will result in the current agreement expiring on its own terms on June 30, 2022. See additional discussion of PNM’s SJGS Abandonment Application in Note 12.

WSJ LLC notified PNM in mid-July that it had encountered unfavorable geologic conditions that were impeding longwall progress in the San Juan Mine. On August 17, 2021, WSJ LLC issued a formal notice of non-normal conditions due to WSJ LLC’s inability to maintain a reserve of coal at required levels. WSJ LLC also notified PNM that these geologic complications constituted a force majeure event that was preventing WSJ LLC from satisfying its obligation to maintain required coal inventory levels. Although geologic conditions are reportedly improving, PNM does not know whether reduced levels of coal inventory may continue until normal conditions recur in the longwall panel or whether the period of non-normal conditions will impact full load operations through the remainder of the year.

The SJGS RA sets forth terms under which PNM acquired the coal inventory, including coal mined but not delivered, of the exiting SJGS participants as of January 1, 2016, and supplied coal to the SJGS exiting participants for the period from January 1, 2016 through December 31, 2017, and is supplying coal to the SJGS remaining participants over the term of the SJGS CSA. Coal costs under the SJGS CSA are significantly less than under the previous arrangement with SJCC. Since substantially all of PNM’s coal costs are passed through the FPPAC, the benefit of the reduced costs is passed through to PNM’s customers.

In connection with certain mining permits relating to the operation of the San Juan mine, the San Juan mine owner 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 the San Juan mine owner, PNMR entered into the WFB LOC Facility under which letters of credit aggregating $30.3 million have been issued. As discussed in Note 6, on March 15, 2019, the assets owned by SJCC were sold to WSJ LLC, a subsidiary of Westmoreland Mining Holdings, LLC. Under the sale agreement, WSJ LLC assumed the rights and obligations of SJCC including obligations to PNMR under the outstanding letters of credit.

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. PNM's share of the coal costs is being recovered through the FPPAC. In connection with the exit of Four Corners, PNM would make payments of $75.0 million to NTEC for relief from its obligations under the coal supply agreements for Four Corners after December 31, 2024. PNM is not proposing to recover the $75.0 million from ratepayers and, if approved as filed, would not be recovered through the FPPAC. See Note 12 for additional information on PNM's Four Corners Abandonment Application. See additional discussion of the Four Corners CSA in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

NTEC has contracted with Bisti Fuels Company, LLC, a subsidiary of The North American Coal Corporation, for management and operation of the mine. Under the CSA, NTEC has the right after a specified period to request approval from the Four Corners owners to replace Bisti Fuels Company as mine manager with NTEC’s internal resources and perform all or some mine management functions. APS granted approval on behalf of the owners on June 16, 2021, subject to certain credit assurance requirements. On June 17, 2021, NTEC notified The North American Coal Corporation that the contract mining agreement between Bisti Fuels Company and NTEC is terminated effective September 30, 2021. NTEC assumed direct operations at Navajo Mine on October 1, 2021.

Coal Mine Reclamation

As indicated under Coal Combustion Residuals Waste Disposal above, SJGS currently disposes of CCRs in the surface mine pits adjacent to the plant and Four Corners disposes of CCRs in ponds and dry storage areas. As discussed in Note 16 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K, in conjunction with the proposed shutdown of SJGS Units 2 and 3 to comply with the BART requirements of the CAA, periodic updates to the coal mine reclamation study were requested by the SJGS participants. These updates have generally increased PNM's share of the estimated cost of mine reclamation and have included adjustments to reflect the December 2017 shutdown of SJGS Units 2 and 3, the terms of the reclamation services agreement with WSJ LLC, and changes to reflect the requirements of the 2015 San Juan mine permit plan.

In late 2020, a mine reclamation cost study was completed for the mine that serves SJGS and in December 2020, PNM remeasured its liability, which resulted in an increase in the overall reclamation costs of $3.6 million, due primarily to higher inflationary factors. As a result, PNM recorded a less than $0.1 million decrease in the liability at December 31, 2020 related to the underground mine and a decrease to the regulatory assets on the Condensed Consolidated Balance Sheets and recorded a $3.6 million increase in the liability associated with the surface mine as regulatory disallowances and restructuring costs on the Condensed Consolidated Statements of Earnings. 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 then 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.

A coal mine reclamation study for the mine that serves Four Corners was issued in 2019. The study reflected operation of the mine through 2031, the term of the Four Corners CSA. The study resulted in a net increase in PNM’s share of the coal mine reclamation obligation of $0.8 million, which was primarily driven by lower overhead costs offset by an increase driven by a reduction in the discount rate used by PNM to measure the liability during the year ended December 31, 2019. As discussed in Note 12, PNM remains responsible for its share of costs associated with mine reclamation under the Four Corners Purchase and Sale Agreement with NTEC. NTEC and PNM will complete a reclamation study in 2024 providing the final mine reclamation cost estimate on the date of ownership transfer. PNM will make its final reclamation payment to NTEC based on the reclamation study in 2024 and will have no further obligations regarding the mine reclamation after 2024. PNM determined that events and circumstances regarding Four Corners, including the Four Corners Purchase and Sale Agreement with NTEC and the Four Corners Abandonment Application, indicated that it is more likely than not that PNM’s share of Four Corners coal mine reclamation obligation would be settled in 2024, rather than 2031. As of December 31, 2020, PNM remeasured its Four Corners coal mine reclamation liability and recorded a decrease to the liability of $2.5 million on the Condensed Consolidated Balance Sheet and a decrease to regulatory disallowances and restructuring costs on the Condensed Consolidated Statement of Earnings.

Based on the most recent estimates, PNM’s remaining payments as of September 30, 2021, for mine reclamation, in future dollars, are estimated to be $75.4 million for the surface mines at both SJGS and Four Corners and $35.1 million for the underground mine at SJGS. At September 30, 2021 and December 31, 2020, liabilities, in current dollars, of $68.3 million and $71.7 million for surface mine reclamation and $27.5 million and $26.1 million for underground mine reclamation were recorded in other deferred credits.

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. The SJGS owners entered into a reclamation trust funds agreement to provide funding to compensate WSJ LLC for post-term reclamation obligations. As discussed in Note 16 of the Notes to the Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K, as part of the restructuring of SJGS ownership, the SJGS owners negotiated the terms of an amended agreement to fund post-term reclamation obligations under the CSA. 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 periodically deposit funds into the reclamation trust for the owner’s share of the mine reclamation obligation. Deposits, which are based on funding curves, must be made on an annual basis. As part of the restructuring of SJGS ownership discussed above, the SJGS participants agreed to adjusted interim trust funding levels. PNM funded $3.2 million in 2020 and, based on PNM’s reclamation trust fund balance at September 30, 2021, the current funding curves indicate PNM’s required contributions to its reclamation trust fund would be $4.8 million in 2021, $6.2 million in 2022, and zero in 2023.

Under the Four Corners CSA, PNM is required to fund its ownership 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 $2.0 million in 2020 and $2.2 million in 2021, and anticipates providing additional funding of $2.1 million in each of the years from 2022 through 2024. As discussed above, under the terms of the Four Corners Purchase and Sale Agreement with NTEC, PNM will make its final reclamation payment to NTEC based on the reclamation study in 2024 and will have no further obligations regarding the mine reclamation.

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 2018 Compliance Filing and its SJGS and Four Corners Abandonment Applications in Note 12. PNM is currently unable to determine the outcome of these matters or the range of possible impacts.

Continuous Highwall Mining Royalty Rate

In August 2013, the DOI Bureau of Land Management (“BLM”) issued a proposed rulemaking that would retroactively apply the surface mining royalty rate of 12.5% to continuous highwall mining (“CHM”).  Comments regarding the rulemaking were due on October 11, 2013, and PNM submitted comments in opposition to the proposed rule. There is no legal deadline for adoption of the final rule.

SJCC, as former owner and operator of San Juan mine, utilized the CHM technique from 2000 to 2003, and with the approval of the Farmington, New Mexico Field Office of BLM to reclassify the final highwall as underground reserves, applied the 8.0% underground mining royalty rate to coal mined using CHM and sold to SJGS.  In March 2001, SJCC learned that the DOI Minerals Management Service (“MMS”) disagreed with the application of the underground royalty rate to CHM.  In August 2006, SJCC and MMS entered into an agreement tolling the statute of limitations on any administrative action to recover unpaid royalties until BLM issued a final, non-appealable determination as to the proper rate for CHM-mined coal.  The proposed BLM rulemaking has the potential to terminate the tolling provision of the settlement agreement. Underpaid royalties of approximately $5 million for SJGS would become due if the proposed BLM rule is adopted as proposed.  PNM’s share of any amount that is ultimately paid would be approximately 46.3%, none of which would be passed through PNM’s FPPAC. PNM is unable to predict the outcome of this matter.

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. In accordance with this act, the PVNGS participants are insured against public liability exposure for a nuclear incident up to $13.5 billion per occurrence. PVNGS maintains the maximum available nuclear liability insurance in the amount of $450 million, which is provided by American Nuclear Insurers. The remaining $13.1 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. Based on PNM’s 10.2% interest in each of the three PVNGS units, as of September 30, 2021, PNM’s maximum potential retrospective premium assessment per incident for all three units is $42.1 million, with a maximum annual payment limitation of $6.2 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 $5.4 million for each retrospective premium assessment declared by NEIL’s Board of Directors due to losses. The insurance coverages discussed in this and the previous paragraph are subject to certain policy conditions, sublimits, and exclusions.

PVNGS Water Supply Litigation

In 1986, an action commenced regarding the rights of APS and the other PVNGS participants to the use of groundwater and effluent at PVNGS. APS filed claims that dispute the court’s jurisdiction over PVNGS’ groundwater rights and their contractual rights to effluent relating to PVNGS and, alternatively, seek confirmation of those rights. In 1999, the Arizona Supreme Court issued a decision finding that certain groundwater rights may be available to the federal government and Native American tribes. In addition, the Arizona Supreme Court issued a decision in 2000 affirming the lower court’s criteria for resolving groundwater claims. Litigation on these issues has continued in the trial court. No trial dates have been set in these matters. PNM does not expect that this litigation will have a material impact on its results of operation, financial position, or cash flows.

San Juan River Adjudication

In 1975, the State of New Mexico filed an action in NM District Court to adjudicate all water rights in the San Juan River Stream System, including water used at Four Corners and SJGS. PNM was made a defendant in the litigation in 1976. In March 2009, then President Obama signed legislation confirming a 2005 settlement with the Navajo Nation. Under the terms of the settlement agreement, the Navajo Nation’s water rights would be settled and finally determined by entry by the court of two proposed adjudication decrees.  The court issued an order in August 2013 finding that no evidentiary hearing was warranted in the Navajo Nation proceeding and, on November 1, 2013, issued a Partial Final Judgment and Decree of the Water Rights of the Navajo Nation approving the proposed settlement with the Navajo Nation. A number of parties subsequently appealed to the New Mexico Court of Appeals. PNM entered its appearance in the appellate case and supported the settlement agreement in the NM District Court. On April 3, 2018, the New Mexico Court of Appeals issued an order affirming the decision of the NM District Court. Several parties filed motions requesting a rehearing with the New Mexico Court of Appeals seeking clarification of the order, which were denied. The State of New Mexico and various other appellants filed a writ of certiorari with the NM Supreme Court. The NM Supreme Court granted the State of New Mexico’s petition and denied the other parties’ requests. The issues regarding the Navajo Nation settlement have been briefed and are awaiting a decision by the NM Supreme Court. Adjudication of non-Indian water rights is ongoing.

PNM is participating in this proceeding since PNM’s water rights in the San Juan Basin may be affected by the rights recognized in the settlement agreement and adjudicated to the Navajo Nation, which comprise a significant portion of water available from sources on the San Juan River and in the San Juan Basin and which have priority in times of shortages. PNM is unable to predict the ultimate outcome of this matter or estimate the amount or range of potential loss and cannot determine the effect, if any, of any water rights adjudication on the present arrangements for water at SJGS and Four Corners. Final resolution of the case cannot be expected for several years. An agreement reached with the Navajo Nation in 1985, however, provides that if Four Corners loses a portion of its rights in the adjudication, the Navajo Nation will provide, for an agreed upon cost, sufficient water from its allocation to offset the loss.

Navajo Nation Allottee Matters

In September 2012, 43 landowners filed a notice of appeal with the Bureau of Indian Affairs (“BIA”) appealing a March 2011 decision of the BIA Regional Director regarding renewal of a right-of-way for a PNM transmission line. The landowners claim to be allottees, members of the Navajo Nation, who pursuant to the Dawes Act of 1887, were allotted ownership in land carved out of the Navajo Nation and allege that PNM is a rights-of-way grantee with rights-of-way across the allotted lands and are either in trespass or have paid insufficient fees for the grant of rights-of-way or both.  The allottees generally allege that they were not paid fair market value for the right-of-way, that they were denied the opportunity to make a showing as to their view of fair market value, and thus denied due process. The allottees filed a motion to dismiss their appeal with prejudice, which was granted in April 2014. Subsequent to the dismissal, PNM received a letter from counsel on behalf of what appears to be a subset of the 43 landowner allottees involved in the appeal, notifying PNM that the specified allottees were revoking their consents for renewal of right of way on six specific allotments.  On January 22, 2015, PNM received a letter from the BIA Regional Director identifying ten allotments with rights-of-way renewals that were previously contested. The

letter indicated that the renewals were not approved by the BIA because the previous consent obtained by PNM was later revoked, prior to BIA approval, by the majority owners of the allotments. It is the BIA Regional Director’s position that PNM must re-obtain consent from these landowners. On July 13, 2015, PNM filed a condemnation action in the NM District Court regarding the approximately 15.49 acres of land at issue. On September 18, 2015, the allottees filed a separate complaint against PNM for federal trespass. On December 1, 2015, the court ruled that PNM could not condemn two of the five allotments at issue based on the Navajo Nation’s fractional interest in the land. PNM filed a motion for reconsideration of this ruling, which was denied. On March 31, 2016, the Tenth Circuit granted PNM’s petition to appeal the December 1, 2015 ruling. Both matters have been consolidated. Oral argument before the Tenth Circuit was heard on January 17, 2017. On May 26, 2017, the Tenth Circuit affirmed the district court. On July 8, 2017, PNM filed a Motion for Reconsideration en banc with the Tenth Circuit, which was denied. The NM District Court stayed the case based on the Navajo Nation’s acquisition of interests in two additional allotments and the unresolved ownership of the fifth allotment due to the owner’s death. On November 20, 2017, PNM filed its petition for writ of certiorari with the US Supreme Court, which was denied. The underlying litigation continues in the NM District Court. On March 27, 2019, several individual allottees filed a motion for partial summary judgment on the issue of trespass. The Court held a hearing on the motion on June 18, 2019, and took the motion under advisement. The parties have reached an agreement in principle. The parties are negotiating the specific terms of the settlement documents. PNM cannot yet determine the outcome of these matters.

Merger-Related Litigation

Six purported shareholders of PNMR filed lawsuits against PNMR and the members of the Board challenging the proposed Merger with Avangrid. The lawsuits all challenged the adequacy of the disclosures in the definitive proxy statement filed by PNMR with the SEC on January 5, 2021, and sought, among other things, to enjoin the Merger or, if the Merger has been consummated, to rescind the Merger or an award of damages, and an award of attorneys’ and experts’ fees and expenses. Five of the lawsuits were filed in the United States District Court for the Southern District of New York and one was filed in the United States District Court for the Eastern District of New York. The lawsuits pending in the Southern District of New York were consolidated in the case captioned In re PNM Resources, Inc. Shareholder Litigation, Consolidated Civil Action No. 1:20-CV-10874. The five plaintiffs in the consolidated action in the Southern District of New York filed notices of voluntary dismissal, and, on April 9, 2021, the Court ordered the Clerk of Court to close the consolidated action and all member cases. All five cases filed in the Southern District of New York have been closed. The case pending in the Eastern District of New York, captioned Durlacher v. PNM Resources, Inc., et al., Case No. 1:21-cv-0024, was not served on the defendants and the plaintiff filed a notice of voluntary dismissal on February 15, 2021. These matters are now concluded.

Texas Winter Storm

In mid-February 2021, Texas experienced a severe winter storm delivering the coldest temperatures in 100 years for many parts of the state. As a result, the ERCOT market was not able to deliver sufficient generation load to the grid resulting in significant, statewide outages as ERCOT directed transmission operators to curtail thousands of firm load megawatts. TNMP complied with ERCOT directives to curtail the delivery of electricity in its service territory and did not experience significant outages on its system outside of the ERCOT directed curtailments. Various regulatory and governmental entities are conducting, or have announced they may conduct, inquiries, investigations and other reviews of the Texas winter storm event. Entities that have announced that they plan to conduct or are conducting such inquiries, investigations and other reviews include FERC, NERC, Texas Reliability Entity Inc., ERCOT, the Texas Legislature, the Texas Attorney General, the PUCT, and the Galveston County District Attorney. Further, lawsuits have been filed against various market participants relating to the power outages resulting from the Texas winter storm, including TNMP. As a utility operating during the Texas winter storm event, there is a risk TNMP could be named in additional lawsuits in the future. TNMP intends to vigorously defend itself against any claims raised. TNMP has deferred bad debt expense from defaulting REPs to a regulatory asset totaling $0.8 million at September 30, 2021, and will seek recovery in a general rate case. At this time, the Company does not expect significant financial impacts related to this event, however, it cannot predict the outcome of such matters or the impact on the ERCOT market.

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Regulatory and Rate Matters

9 Months Ended

Sep. 30, 2021

Regulated Operations [Abstract]

Regulatory and Rate Matters

Regulatory and Rate MattersThe Company is involved in various regulatory matters, some of which contain contingencies that are subject to the same uncertainties as those described in Note 11. Additional information concerning regulatory and rate matters is contained in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

PNM

Renewable Portfolio Standard

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 RCT for the procurement of renewable resources to prevent excessive costs being added to rates. The ETA sets a RCT of $60 per MWh 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 a rate rider. See Renewable Energy Rider below.

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 current capacity of 11 MW

•Solar distributed generation, aggregating 190.8 MW at September 30, 2021, owned by customers or third parties from whom PNM purchases any net excess output and RECs

Renewable Energy Rider

The NMPRC has authorized PNM to recover certain renewable procurement costs through a rate rider billed on a per KWh basis. In its 2020 renewable energy procurement plan, which became effective on January 1, 2021, PNM proposed to collect $67.8 million for the year. The NMPRC approved recovery of $65.5 million through the rider, reflecting the rejection of PNM's request to recover the $2.3 million Sky Blue regulatory asset in 2021. PNM recorded revenues from the rider of $13.0 million and $44.4 million in the three and nine months ended September 30, 2021, and $12.0 million and $42.3 million in the three and nine months ended September 30, 2020. On June 1, 2021 PNM filed its renewable energy procurement plan for 2022 which proposes to collect $66.9 million for the year. PNM is not proposing any new procurements in the plan but is proposing to retire a small number of RECs in 2022 from resources that have not been previously approved as part of the RPS plan. The NMPRC assigned this matter to a hearing examiner and a hearing was held on September 30, 2021. On October 15, 2021, NMPRC Staff and PNM jointly filed the post-hearing brief stating that pending issues to the case had been resolved with PNM agreeing to certain compliance provisions. On October 20, 2021, the hearing examiner issued an order regarding briefing and exceptions stating that the forthcoming recommended decision should be uncontroversial and time offered for exceptions will likely be minimal.

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 did not exceed such limitation in 2020.

Energy Efficiency and Load Management

Program Costs and Incentives/Disincentives

The New Mexico Efficient Use of Energy Act (“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 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 not exceed seventy-five thousand dollars.

In 2019, PNM submitted a filing to address incentives to be earned in 2020. PNM’s proposed incentive mechanism was similar to that approved for 2018 and 2019 with minor modifications to reflect input from interested parties. The proposed incentive mechanism includes a base incentive of 7.1% of program costs, or approximately $1.8 million, based on savings of 59

GWh in 2020 with a sliding scale that provides for additional incentive if savings exceed 68 GWh. No hearings were considered necessary and PNM’s 2020 energy efficiency rider reflecting the 2020 incentive became effective beginning December 30, 2019. On April 15, 2021 PNM filed its 2020 Energy Efficiency Annual Report which reconciles the actual 2020 profit incentive collections with the profit incentive authorized by the NMPRC resulting in an additional $0.8 million incentive to be collected during the remainder of 2021. The additional incentive was authorized for 2020 because annual energy savings for the year exceeded 87 GWh, and was the maximum level of profit incentive allowed under the approved mechanism. PNM began collecting the additional incentive effective May 27, 2021.

On April 15, 2020, PNM filed an application for energy efficiency and load management programs to be offered in 2021, 2022, and 2023. The proposed program portfolio consists 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 application also sought approval of 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 proposed incentive would increase if PNM is able to achieve savings greater than 80 GWh in a year. The application also proposed an advanced metering infrastructure (“AMI”) pilot program, which included the installation of 5,000 AMI meters at a cost of $2.9 million. PNM proposed the pilot program to comply with an NMPRC order denying PNM’s February 2016 application to replace its existing customer metering equipment with AMI. PNM did not recommend the AMI pilot program due to the limited benefits that are cost-effective under a pilot structure. On September 17, 2020, the hearing examiner in the case issued a recommended decision recommending that PNM's proposed energy efficiency and load management program be approved, with the exception of the proposed AMI pilot program. On October 28, 2020, the NMPRC issued an order adopting the recommended decision 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. PNM proposed to record the difference between the annual revenue per customer derived from the cost of service approved in the NM 2015 Rate Case and the annual revenue per customer actually recovered from the rate classes beginning on January 1, 2021. If approved, on January 1, 2022, PNM would begin to collect the difference from customers if the revenue per customer from the NM 2015 Rate Case exceeds the actual revenue recovered in 2021, or return the difference to customers if the actual revenue per customer recovered in 2021 exceeds the revenue per customer from the NM 2015 Rate Case. 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 allege that PNM’s proposed rate adjustment mechanism is inconsistent with the EUEA. Responses to the motions to dismiss were filed on August 7, 2020. On September 16, 2020, ABCWUA, Bernalillo County, CCAE, the City of Albuquerque, NEE, NMAG, NMPRC Staff ("Staff") and WRA filed testimony. CCAE and WRA support PNM's petition, but recommend that the rate adjustment mechanism not take effect until new rates are approved in PNM's next general rate case. The other parties filing testimony oppose PNM's petition. 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 November 24, 2020, the NMAG requested that the NMPRC deny both petitions for declaratory orders and instead address disincentives under the EUEA in a rulemaking. On March 17, 2021, the NMPRC issued an order granting the petitions for declaratory order, commencing a declaratory order proceeding to address the petitions, denying the NMAG’s request to initiate a rulemaking, and appointing a hearing examiner to preside over the declaratory order proceeding. Initial briefs were filed on June 7, 2021 and response briefs were filed on June 28, 2021. Oral arguments were made on July 15, 2021. PNM cannot predict the outcome of this matter.

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 four years of that period.

2020 IRP

NMPRC rules required PNM to file its 2020 IRP in July 2020. On March 16, 2020, PNM filed a motion to extend the deadline to file its 2020 IRP to six months after the NMPRC issues a final order approving a replacement resource portfolio and closes the docket in the bifurcated SJGS Abandonment Application and replacement resource proceedings. On April 8, 2020, the NMPRC approved PNM's motion to extend the deadline to file its 2020 IRP as requested. On January 29, 2021, PNM filed its 2020 IRP addressing the 20-year planning period from 2020 through 2040. The plan focuses on a carbon-free electricity portfolio by 2040 that would eliminate coal at the end of 2024. This includes replacing the power from San Juan with a mix of approved carbon-free resources and the plan to exit Four Corners at the end of 2024. The plan highlights the need for additional investments in a diverse set of resources, including renewables to supply carbon-free power, energy storage to balance supply and demand, and efficiency and other demand-side resources to mitigate load growth. On May 24, 2021, the hearing examiner issued a procedural schedule and required PNM, upon request, to provide modeling data and assumptions to parties within two weeks. Additionally, PNM is required upon request, to run modeling or provide reasonable access to PNM virtual machines at PNM's expense. The alternative modeling deadline concluded on August 30, 2021 and Staff's recommendation is due on November 11, 2021.

Abandonment Applications made under the ETA

As discussed in Note 11, the 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 also 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 the qualifying utility.

SJGS Abandonment Application

On July 1, 2019, PNM filed a Consolidated Application for the Abandonment and Replacement of SJGS and Related Securitized Financing Pursuant to the ETA (the “SJGS Abandonment Application”). The SJGS Abandonment Application sought NMPRC approval to retire PNM’s share of SJGS after the existing coal supply and participation agreements end in June 2022, for approval of replacement resources, and for the issuance of approximately $361 million of energy transition bonds (the “Securitized Bonds”). PNM’s request for the issuance of Securitized Bonds included approximately $283 million of forecasted undepreciated investments in SJGS at June 30, 2022, an estimated $28.6 million for plant decommissioning and coal mine reclamation costs, approximately $9.6 million in upfront financing costs, and approximately $20.0 million for job training and severance costs for affected employees. Proceeds from the Securitization Bonds would also be used to fund approximately $19.8 million for economic development in the four corners area.

On July 10, 2019, the NMPRC issued an order requiring the SJGS Abandonment Application be considered in two proceedings: one addressing SJGS abandonment and related financing and the other addressing replacement resources. After multiple filings, proceedings, requests for clarification and legal challenges, on January 29, 2020, the NM Supreme Court issued a ruling requiring the NMPRC to apply the ETA to all aspects of PNM’s SJGS Abandonment Application, indicating any previous NMPRC orders inconsistent with the ruling should be vacated, and denying parties’ request for stay. The NM Supreme Court issued a subsequent opinion, on July 23, 2020, more fully explaining the legal rationale for the January 29, 2020 ruling. Hearings on the abandonment and securitized financing proceedings were held in December 2019 and hearings on replacement resources were held in January 2020.

On February 21, 2020, the hearing examiners issued two recommended decisions recommending approval of PNM’s proposed abandonment of SJGS, subject to approval of replacement resources, and approval of PNM’s proposed financing order to issue Securitized Bonds.  The hearing examiners recommended that PNM be authorized to abandon SJGS by June 30, 2022, and to record regulatory assets for certain other abandonment costs that are not specifically addressed under the provisions of the ETA to preserve its ability to recover the costs in a future general rate case. The hearing examiner recommended that this authority only extend to the deferral of the costs and it not be an approval of any ratemaking treatment. The hearing examiners also recommended PNM be authorized to issue Securitized Bonds of up to $361 million and establish an Energy Transition Charge. The hearing examiners recommended an interim rate rider adjustment upon the start date of the Energy Transition Charge to provide immediate credits to customers for the full value of PNM’s revenue requirement related to SJGS until those reductions are reflected in base rates. In addition, the hearing examiners recommended PNM be granted authority to establish regulatory assets to recover costs that PNM will pay prior to the issuance of the Securitized Bonds,

including costs associated with the bond issuances as well as for severances, job training, economic development, and workforce training. On April 1, 2020, the NMPRC unanimously approved the hearing examiners' recommended decisions regarding the abandonment of SJGS and the related securitized financing under the ETA.

On April 10, 2020, CFRE and NEE filed a notice of appeal with the NM Supreme Court of the NMPRC's approval of PNM's request to issue securitized financing under the ETA. The NM Supreme Court granted motions to intervene filed by PNM, WRA, CCAE, and the Sierra Club. On May 8, 2020, CFRE and NEE filed a joint statement of issues with the NM Supreme Court which asserts that the NMPRC improperly applied the ETA and that the ETA violates the New Mexico Constitution. On June 19, 2020, WRA filed a motion to dismiss CFRE and NEE’s constitutional challenges to the ETA on the ground that the New Mexico Constitution provides that only New Mexico district courts have original jurisdiction over the claims. On July 24, 2020, the NM Supreme Court issued an order denying WRA’s motion to dismiss. On August 17, 2020, the appellants filed a Brief in Chief and on October 5, 2020, PNM, WRA, CCAE and Sierra Club filed Answer Briefs. PNM cannot predict the outcome of this matter.

PNM evaluated the consequences of the NMPRC's April 1, 2020 orders approving the abandonment of SJGS and the related issuance of Securitized Bonds. This evaluation indicated that it is probable that PNM will be required to fund severances for PNM employees at the facility upon its retirement in 2022 and for PNMR shared services employees providing administrative and other support services to SJGS. In addition, the evaluation indicated that it is probable PNM will be obligated to fund severances and other costs for the WSJ LLC employees and to fund certain state agencies for economic development and workforce training upon the issuance of the Securitized Bonds. As a result, in March 2020, PNMR and PNM recorded obligations of $9.4 million and $8.1 million for estimated severances, $8.9 million for obligations to fund severances and other costs of WSJ LLC employees, and to fund $19.8 million to state agencies for economic development and workforce training upon the issuance of the Securitized Bonds. The total amount recorded for these estimates of $38.1 million and $36.8 million is reflected in other deferred credits and as a corresponding deferred regulatory asset on PNMR's and PNM's Condensed Consolidated Balance Sheets at December 31, 2020. These estimates may be adjusted in future periods as the Company refines its expectations. In addition, as discussed above these costs may be challenged by parties pursuant to the notices of appeal filed with the NM Supreme Court on April 10, 2020.

On June 24, 2020, the hearing examiners issued a recommended decision on PNM's request for approval of replacement resources that addressed the entire portfolio of replacement resources, which superseded a previous partial recommended decision issued on March 27, 2020. The hearing examiners concluded that the ultimate selection of a portfolio of replacement resources involves policy considerations that are the province of the NMPRC and stated that they did not intend to make that decision for the NMPRC. On July 29, 2020, the NMPRC issued an order approving resource selection criteria identified in the ETA and would include PPAs for 650 MW of solar and 300 MW of battery storage. The order also granted in part PNM’s request for an extension of time for PNM to file the application to implement the replacement resource portfolio. PNM had 60 days from the date of the order to file an application in a separate docket seeking approval of the proposed final, executed contracts, for any replacement resources that are not currently in evidence that have been approved by the NMPRC.

On September 28, 2020, PNM filed its application for approval of the final executed contracts for the replacement resources. In addition, PNM provided updated cost estimates of $8.1 million for the SJGS replacement resources, based on the NMPRC authorization to create regulatory assets granted in the abandonment order, which it plans to seek recovery of in a future general rate case. On November 13, 2020, the hearing examiner issued a recommended decision recommending approval of a 200 MW solar PPA combined with a 100 MW battery storage agreement and a 100 MW solar PPA combined with a 30 MW battery storage agreement. On December 2, 2020, the NMPRC issued an order adopting the recommended decision in its entirety. On May 24, 2021, PNM filed a notice that informed the NMPRC that a solar PPA for 100 MW with battery storage of 30 MW, which was approved as a replacement resources for SJGS, will not be completed in time to serve PNM’s load during the 2022 summer peak season. On July 22, 2021, PNM filed notice to the NMPRC that as a result of supply chain delays, two additional approved replacement resource projects will not be fully completed in time to serve load during the 2022 summer peak season. Specifically, a 200 MW solar PPA with battery storage of 100 MW will only have 50 MW of available capacity in June 2022 and then ramp up through the summer and fall, and a 300 MW solar PPA with battery storage of 150 MW will initially have only 150 MW of solar and 150 MW of battery storage available in June 2022 and is planned to ramp up to full capacity in September 2022. PNM's existing resources, including available reserves, may have been insufficient for 2022 summer peak load reliability considering these delays. As a result, PNM entered into three agreements to purchase power from third parties in the third quarter to ensure customer demand during the 2022 summer peak load period is met; the purchase of 85 MW, unit contingent from Four Corners for June through September of 2022; the purchase of 150 MW, firm power in June and September 2022; and the purchase of 40 MW, unit contingent from PVNGS Unit 3 for the full year of 2022.

Additional information concerning the SJGS Abandonment Application is contained in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

Four Corners Abandonment Application

On November 1, 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. The sale is contingent upon NMPRC approval and expected to close by the end of 2024. 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. Pursuant to the Four Corners Purchase and Sale Agreement, PNM will retain its current plant decommissioning and coal mine reclamation obligations, subject to the final mine reclamation study and payment at the end of 2024. PNM will have no obligation for reclamation after 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 would make a final payment of $60.0 million. The initial $15.0 million payment was recorded in other current assets on the Consolidated Balance Sheet as of December 31, 2020.

On January 8, 2021, PNM filed the Four Corners Abandonment Application, which seeks NMPRC approval to exit PNM’s share of Four Corners as of December 31, 2024, and to issue approximately $300 million of energy transition bonds as provided by the ETA. PNM’s request for the issuance of Securitized Bonds included approximately $272 million of forecasted undepreciated investments in Four Corners at December 31, 2024, an estimated $4.6 million for plant decommissioning costs, estimated $7.3 million in upfront financing costs, and estimated $16.5 million in economic development. PNM intends to submit a separate application for NMPRC approval of a replacement resource portfolio following NMPRC action on this application.

On January 26, 2021, Sierra Club filed a motion in the Four Corners Abandonment Application requesting that the NMPRC order PNM to file supplemental testimony addressing the prudence of Four Corners investments or alternatively that the NMPRC dismiss the Four Corners Abandonment Application and permit PNM to refile after the prudence issue is resolved. In addition, on January 28, 2021, NEE and CFRE filed a motion requesting that the NMPRC dismiss the application, stating that approval of the abandonment would be contrary to the provision of the REA that prevents the sale of carbon dioxide emitting electricity-generating resources as a means of complying with the RPS, and that the Four Corners Abandonment Application does not demonstrate that the sale of 200 MW to NTEC will not result in a net detriment to public interest. On February 26, 2021, the hearing examiner issued an order on the sufficiency of the Four Corners Application finding that the application was deficient on its face and failed to adequately support whether or not the sale and transfer of PNM’s interest in Four Corners to NTEC is in the public interest. However, given the NMPRC’s preference to address Four Corners issues in the case, as well as PNM’s concession on filing an amended application, the hearing examiner did not recommend that the case be dismissed. The order required PNM to file an amended application by March 15, 2021; established that the nine-month period for review of the amended application shall start on the date of PNM’s filing of the amended application and run through December 15, 2021; required PNM to file supplemental testimony addressing the prudence of its investment in Four Corners; required PNM to more explicitly address the statutory standards for approval of the proposed transfer to NTEC; and required PNM to file a motion to withdraw the January 8, 2021 Four Corners Application. On March 15, 2021, PNM filed an amended application and supplemental testimony for the approval of the abandonment and transfer of Four Corners and issuance of a financing order pursuant to the ETA and a motion to withdraw the January 8, 2021 Four Corners Application. The amended application and supplemental testimony provided additional information to support PNM's request to abandon its interest in Four Corners and transfer that interest to NTEC, and also provided additional detail explaining how the proposed sale and abandonment provides a net public benefit. A hearing began August 31, 2021, briefs were filed October 1, 2021 and response briefs were filed October 13, 2021.

On May 17, 2021 NEE and CFRE ("Joint Movants") again filed motions to dismiss the case, providing reasons which include; PNM's failure to disclose the reason for the divestiture in the plant is the Merger; the application is deficient because PNM has failed to produce the seasonal operation agreement with the other Four Corners owners; and reiterated their prior view that PNM's amended application is contrary to the REA. Also on May 17, 2021, CCAE filed a motion to dismiss the case stating that PNM's application is devoid of any discussion of the assumption of liabilities by NTEC pertaining to PNM's share of Four Corners. On May 18, 2021, San Juan Citizens Alliance/Dine Care and the Native American Voters Alliance Education Project ("NAVAEP") filed a joinder supporting CCAE's motion. On June 1, 2021, PNM filed responses to the Joint Movants' and CCAE motions to dismiss and filed a motion to strike portions of the Joint Movants' and CCAE's motions to dismiss. PNM's motion states that the Joint Movants and CCAE rely upon materials beyond the pleadings in the case and within the

record in other proceedings to support their motions. On June 14, 2021 the hearing examiner issued an order denying the motions to dismiss from NEE, CFRE and CCAE.

On October 30, 2020, NEE filed a formal complaint with the NMPRC seeking an investigation into the reasonableness and lawfulness of PNM’s continued reliance on “climate-altering and uneconomic coal” at Four Corners. NEE explained that they withdrew their Supreme Court appeal of the NM 2016 Rate Case under the notion that PNM would be filing a rate case in 2019 and they would be able to challenge the Four Corners expenditures in that case. NEE explained that because PNM has delayed its rate case several times, Four Corners has remained “imprudently” in rates. NEE asked that PNM be required to demonstrate that PNM’s investment in Four Corners was prudent. NEE stated if the NMPRC deems PNM’s investment as imprudent, ratepayers will be held harmless and all costs including carrying charges, effective October 30, 2020, and going forward, be denied. On February 10, 2021, the NMPRC denied NEE’s complaint and stated that issues related to Four Corners prudence should be addressed in the Four Corners Abandonment Application. On February 22, 2021, NEE filed a Motion for Reconsideration of the NMPRC’s February 10, 2021 order, which was denied on March 10, 2021. On April 9, 2021, NEE filed a Notice of Appeal with the NM Supreme Court regarding their formal complaint on Four Corners. On July 6, 2021, NEE filed a motion to withdraw its Notice of Appeal with the NM Supreme Court. On September 21, 2021 the NM Supreme Court issued its order granting NEE's motion to withdraw its appeal; the court also issued a mandate to the NMPRC to take further action as might be needed consistent with the order.

The financial impact of an early exit of Four Corners and the NMPRC approval process are influenced by many factors outside of PNM’s control, including the overall political and economic conditions of New Mexico. See additional discussion of the ETA in Note 11. PNM cannot predict the outcome of these matters.

PVNGS Leased Interest Abandonment Application

On April 2, 2021, PNM filed an application with the NMPRC requesting approval for the decertification and abandonment of 114 MW of leased PVNGS capacity, sale and transfer of related assets, and approval to procure new resources ("PVNGS Leased Interest Abandonment Application"). As discussed in Note 13, PNM currently controls leased capacity in PVNGS Unit 1 and Unit 2 under five separate leases ("Leased Interest") that were approved and certificated by the predecessor agency to the NMPRC in the 1980s. Four of the five leases for 104 MW of Leased Interest terminate on January 15, 2023, while the remaining lease for 10 MW of Leased Interest terminates on January 15, 2024. Associated with the Leased Interest are certain PNM-owned assets and nuclear fuel that are necessary for the ongoing operation and maintenance of the Leased Interest and integration of the Leased Interest generation to the transmission network. PNM has determined that there will be net benefits to its customers to return the Leased Interest to the lessors in conformity with the leases, sell and transfer the related PNM-owned assets, and to replace these Leased Interest with new resources. In the application PNM is requesting NMPRC authorization to decertify and abandon its Leased Interest and to create regulatory assets for the associated remaining undepreciated investments with consideration of cost recovery of the undepreciated investments in a future rate case. PNM is also seeking NMPRC approval to sell and transfer the PNM-owned assets and nuclear fuel supply associated with the Leased Interest to SRP, which will be acquiring the Leased Interest from the lessors upon termination of the existing leases. In addition, PNM is seeking NMPRC approval for a 150 MW solar PPA combined with a 40 MW battery storage agreement, and a stand-alone 100 MW battery storage agreement to replace the Leased Interest. To ensure system reliability and load needs are met in 2023, when a majority of the leases expire, PNM is also requesting NMPRC approval for a 300 MW solar PPA combined with a 150 MW battery storage agreement. PNM's application sought a six-month regulatory time frame. On April 21, 2021, the NMPRC issued an order assigning a hearing examiner and stated PNM's request to abandon the Leased Interest does not have any statutory or rule time limitation and the six-month limit in which the NMPRC must issue an order regarding the request for approvals of the solar PPAs and battery storage agreements does not begin until after the NMPRC acts on the abandonment request. On June 14, 2021 and June 25, 2021 PNM filed supplemental testimony responding to questions provided by the hearing examiner. On June 28, 2021, NEE and CCAE jointly filed a motion to dismiss a portion of the application claiming that since PNM's request to abandon the Leased Interest was filed after PNM had already provided irrevocable notice it would not acquire the Leased Interest, abandonment is no longer required. On July 28, 2021, the hearing examiner issued a recommended decision on NEE's and CCAE's joint motion to dismiss, recommending dismissal of PNM's requests for approval to abandon and decertify the Leased Interest; dismissal of PNM's request for approval to sell and transfer the related assets; and dismissal of PNM's request to create regulatory assets for the associated remaining undepreciated investments, but does not preclude PNM seeking recovery of the costs in a general rate case in which the test year period includes the time period in which PNM incurs such costs. The hearing examiner's recommended decision further provides that PNM's request for replacement and system reliability resources should remain within the scope of this case. On August 25, 2021, the NMPRC issued an order granting portions of the July 28, 2021 recommended decision that were not contested related to dismissal of PNM's request for approval to abandon and decertify the Leased Interest and dismissal of PNM's request for approval to sell and transfer the related assets. In addition, the order bifurcated the issue of approval for the two PPAs and three

battery storage agreements into a separate docket so it may proceed expeditiously. On September 8, 2021 the NMPRC issued an order on the remaining issues in the recommended decision. The order found that PNM's request for a regulatory asset to record costs associated with obtaining an abandonment order should be dismissed. However, the requests for regulatory assets associated with the remaining undepreciated investments should be addressed at an evidentiary hearing. On September 20, 2021, ABCWUA, Bernalillo County, NEE and the NMAG filed a joint motion to reconsider the September 8, 2021 NMPRC order. Also, on September 20, 2021, PNM filed a motion for rehearing of the September 8, 2021 order stating that certain requirements of the order would lead to compromising PNM's First Amendment rights. On October 6, 2021, the NMPRC issued an order granting the motions for reconsideration and vacated the September 8, 2021 order, without specifically addressing issues raised in the motions. A hearing on the two PPAs and three battery storage agreements is scheduled for November 11, 12 and 15, 2021.

In addition to approval by the NMPRC, PNM and SRP requires NRC approval for the transfer of the associated possessory licenses at the end of the term of each of the respective leases. PNM cannot predict the outcome of this matter.

Facebook, Inc. Data Center Project

PNM has a special service contract to provide service to Facebook, Inc. for a data center being constructed in PNM’s service area. Facebook’s service requirements include the acquisition by PNM of a sufficient amount of new renewable energy resources and RECs to match the energy and capacity requirements of the data center. The cost of renewable energy procured is passed through to Facebook under a rate rider. A special service rate is applied to Facebook’s energy consumption in those hours of the month when their consumption exceeds the energy production from the renewable resources. As of September 30, 2021, PNM is procuring energy from 130 MW of solar-PV capacity from NMRD, a 50% equity method investee of PNMR Development. See additional discussion of NMRD in Note 16.

PNM has NMPRC approval for several PPAs to purchase renewable energy and RECs to supply renewable energy to the data center. Details related to these PPAs can be found in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

On February 8, 2021, PNM filed an application with the NMPRC for approval to service the data center for an additional 190 MW of solar PPA combined with 100 MW of battery storage and a 50 MW solar PPA expected to be operational in 2023. On April 28, 2021, the NMPRC issued an order finding that a hearing will be held with a hearing examiner presiding. On June 16, 2021 a hearing was held by the NMPRC with closing statements filed on June 21, 2021. On June 23, 2021, the NMPRC issued an Order for Continuance, stating concerns with the proposed addendum to the special service contract and its methodology for calculating a credit to Facebook for the capacity supplied by the 100 MW battery storage agreement. To address these concerns the Order required PNM and Facebook to renegotiate the addendum to the special service contract and the battery storage agreement. Additionally, the NMPRC designated a mediator to the facilitate the negotiations. PNM was ordered to file a renegotiated modification to its application by July 14, 2021 with responses from other parties due July 21, 2021. On July 6, 2021, PNM filed a Motion for Rehearing stating that the NMPRC's June 23, 2021 Order for Continuance contains substantive issues including misstatement of facts presented during the hearing on PNM’s application, which must be amended or withdrawn on rehearing. PNM’s motion also pointed out procedural issues with the order, including requiring mediation with Facebook who is not a party to the case while not including Staff, who is the only party to disagree with PNM’s application; and requiring PNM and Facebook to agree to modifications of the special service contract with which they are not in agreement, are not part of the application, and has not been vetted at hearing. On July 7, 2021, the NMPRC designated mediator issued a report cancelling the schedule mediation because PNM and Facebook were not willing to participate. On July 14, 2021, the NMPRC issued an order granting PNM's Motion for Rehearing and scheduling a further public hearing for July 23, 2021. The NMPRC vacated the public hearing in response to Facebook’s inability to provide a witness to testify at the hearing. On July 28, 2021, the NMPRC issued a final order reversing the order granting a rehearing; approved the solar PPAs for 190 MW and 50 MW; approved only 50 MW of the requested 100 MW battery storage; and rejected the proposed addendum to the special service contract and its methodology for calculating a credit to Facebook for the capacity supplied by the battery storage. On October 1, 2021, in compliance with the final order, PNM filed a Notice of Filing Amendments recognizing that the battery storage is 50 MW instead of 100 MW and PPA and battery storage requirements for approval of the addendum to the special service contract is waived. This matter is now concluded.

COVID-19 Regulatory Matters

In March 2020, PNM and other utilities voluntarily implemented a temporary suspension of disconnections and late payment fees for non-payment of utility bills in response to the impacts of the novel coronavirus global pandemic (“COVID-19”). On March 18, 2020, the NMPRC conducted an emergency open meeting for the purpose of adopting emergency amendments to its rules governing service to residential customers. The NMPRC’s emergency order is applicable during the duration of the Governor of New Mexico's emergency executive order and allowed for the closure of payment centers, prohibited the discontinuance of a residential customer’s service for non-payment, and suspends the expiration of medical certificates for certain customers. On April 27, 2020, PNM, El Paso Electric Company, New Mexico Gas Company, and Southwestern Public Service Company filed a joint motion with the NMPRC requesting authorization to track costs resulting from each utility's response to the COVID-19 outbreak. The utilities proposed these incremental costs and uncollected customer accounts receivable resulting from COVID-19 during the period March 11, 2020 through December 31, 2020, be recorded as a regulatory asset. On June 24, 2020, the NMPRC issued an order authorizing all public utilities regulated by the NMPRC to create a regulatory asset to defer incremental costs related to COVID-19, including increases to bad debt expense incurred during the period beginning March 11, 2020 through the termination of the Governor of New Mexico’s emergency executive order. The NMPRC order requires public utilities creating regulatory assets to pursue all federal, state, or other subsidies available, to record a regulatory liability for all offsetting cost savings resulting from the COVID-19 pandemic, and allows PNM to request recovery in future ratemaking proceedings. As a result, PNM has deferred incremental costs related to COVID-19 of $13.2 million and $8.8 million in regulatory assets on the Condensed Consolidated Balance Sheet at September 30, 2021 and December 31, 2020. In addition, PNM has costs savings related to COVID-19 of $0.9 million in regulatory liabilities on the Condensed Consolidated Balance Sheet at September 30, 2021 and December 31, 2020. The NMPRC’s order also imposed additional quarterly reporting requirements on public utilities creating regulatory assets that include changes in customer usage and increased costs and savings recorded to regulatory assets and liabilities.

On February 3, 2021, the NMPRC issued an order finding that the temporary mandatory moratorium on disconnections of residential utility customers shall be in effect from the date of the order for 100 days, which ended May 14, 2021. At the end of the moratorium, the 90-day transition period began, which continued the temporary moratorium on disconnections to provide the utilities additional time to assist residential customers with arrearages to enter into installment agreements. On July 14, 2021, the NMPRC issued an order clarifying previous orders that the mandatory requirements of the NMPRC's previous order prohibiting residential disconnects should be voluntarily complied with by investor-owned utilities until August 12, 2021. PNM began disconnections at the end of the transition period.

Transportation Electrification Program

On December 18, 2020, in compliance with New Mexico Statute, PNM filed its PNM 2022-2023 Transportation Electrification Program (“TEP”) for approval with the NMPRC. PNM’s requested TEP includes a budget of approximately $8.4 million with flexibility of 25%. As proposed, up to 25% of the program budget will be dedicated to low and moderate income customers and is based on a model with no company ownership of charging facilities. PNM’s proposed TEP provides incentives through rebates to both residential and non-residential customers towards the purchase of chargers and/or behind-the-meter infrastructure. PNM’s TEP includes a request for a modified rate to add an electric vehicle pilot with a time-of-use option, a new non-residential electric vehicle time-of-use rate pilot without demand charges and implementation of a new rider to collect the actual costs of the TEP. PNM’s application requested NMPRC approval by the end of August 2021 and authority to file a new TEP by the end of June 2023. A hearing was held the week of May 24, 2021. On August 30, 2021 the hearing examiner issued a recommended decision approving, among other things, PNM's budget flexibility proposal, PNM's proposed pilot time-of-use rate and PNM's TEP Rider. Exceptions to the recommended decision were filed on September 24, 2021. PNM cannot predict the outcome of this matter.

Unexecuted Transmission Service Agreements (TSAs) with Leeward Renewable Energy

On March 12, 2021, PNM filed four unexecuted TSAs with FERC totaling 145 MW with Leeward Energy. The unexecuted TSAs provide long-term firm, point-to-point transmission service on PNM’s transmission system. The unexecuted TSAs are based on the pro-forma transmission service agreements with certain non-conforming provisions under Attachment A of PNM’s OATT and include PNM’s OATT rate. PNM is filing the unexecuted TSAs at the request of Leeward because the parties have been unable to reach an agreement on the terms and conditions for transmission service. In particular, Leeward believes the rate under the unexecuted TSAs should be an incremental rate while PNM believes the appropriate rate is its OATT rate.

On April 2, 2021, Leeward Energy and Pattern Energy separately protested PNM’s March 12, 2021 filing of four unexecuted TSAs with Leeward Energy. The parties are requesting that FERC direct PNM to apply the same rate to the unexecuted TSAs as the incremental rate assessed to the Western Spirit transmission facilities, inclusive of Leeward’s network upgrades and requested service, or, in the alternative, initiate hearing and settlement judge procedures to address the unjust and unreasonable application of the FERC’s “higher of” policy. On April 19, 2021, PNM filed a motion for leave to answer and contested the arguments made by Leeward Energy and Pattern Energy. In its response, PNM stated that it disagrees with the parties' pricing scheme because doing so would not recognize all the transmission facilities necessary to provide Leeward service, does not hold PNM's other transmission customers harmless, and is inconsistent with FERC pricing policy and precedent. PNM further explained that the proposal to include its FERC approved embedded rate in the unexecuted TSAs is just and reasonable and should be accepted by FERC. On May 11, 2021, FERC issued an order accepting PNM's four unexecuted TSAs. In the order, FERC stated that it agreed with PNM's pricing scheme and agreed that PNM's proposal to use the OATT rate will ensure that the benefit of Leeward's addition to the system will be spread among other existing system users, rather than simply transferred to Pattern. On June 10, 2021, Pattern and Leeward both filed a request for rehearing of the FERC Order. On September 10, 2021, Leeward filed a petition in the United States District Court for the District of Columbia for review of FERC's order accepting PNM's four unexecuted TSAs. PNM cannot predict the outcome of this matter.

FERC Compliance

PNM is conducting 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. PNM anticipates it will pursue any applicable waivers with FERC upon completion of PNM’s internal review. PNM is unable to predict the outcome of this matter.

The Community Solar Act

On June 18, 2021, Senate Bill 84, known as the Community Solar Act, became effective. The Community Solar Act establishes a program that allows for the development of community solar facilities and provides customers of a qualifying utility with the option of accessing solar energy produced by a community solar facility in accordance with the Community Solar Act. The NMPRC is charged with administering the Community Solar Act program, establishing a total maximum capacity of 200 MW community solar (applicable until November 2024) facilities and allocating proportionally to the New Mexico electric investor-owned utilities and participating cooperatives. As required under the Community Solar Act, the NMPRC opened a docket on May 12, 2021 to adopt rules to establish a community solar program no later than April 1, 2022. On June 15, 2021, the NMPRC issued an order which required utilities provide a notice to all future applicants and to any likely applicants that, until the effective date of the NMPRC's rules in this area the NMPRC's existing interconnection rules and manual remain in place until amended or replaced by the NMPRC, and further, that a place in a utility's applicant queue for interconnection does not and will not provide any advantage for selection as a community solar project. PNM has provided the required notices. On October 27, 2021, the NMPRC adopted an order issuing a Notice of Proposed Rulemaking starting the formal process for adoption of rules pursuant to the Community Solar Act. PNM cannot predict the full impact of the Community Solar Act or the outcome of the NMPRC's rulemaking.

San Juan Generating Station Unit 1 Outage

On June 30, 2021, a cooling tower used for SJGS Unit 1 failed resulting in a unit outage. SJGS Unit 1 was brought back online on July 25, 2021. PNM anticipates the damages to the facility will be reimbursed under an existing property insurance policy that covers SJGS, subject to a deductible of $2.0 million. PNM’s exposure to the cost of repairs is $1.0 million, reflecting PNM’s 50% ownership interest in SJGS Unit 1. On July 14, 2021, the NMPRC issued an order opening a formal docket and inquiry into the cooling tower incident. PNM has responded to a number of NMPRC questions in the inquiry, including questions about the cause of the cooling tower failure, cost and progress of the cleanup and remediation, whether customers experienced loss of service, how PNM provided power during the outage, safety practices and procedures at SJGS, and the history of inspections on the cooling towers. PNM cannot predict the outcome of this matter.

TNMP

Recovery of TNMP Rate Case Costs

Recovery of the cost of TNMP’s rate case was moved into a separate proceeding to begin after the conclusion of the TNMP 2018 Rate Case discussed in the 2020 Annual Reports on Form 10-K. TNMP sought recovery of costs incurred through August 2019 in the amount of $3.8 million and proposed these costs be collected from customers over a three-year period. In

October 2019, TNMP and other parties to the proceedings filed an unopposed settlement stipulation that reduced TNMP’s cost recovery to $3.3 million and provide for recovery over a period not to exceed three-years beginning on March 1, 2020. On January 16, 2020, the PUCT approved the settlement. As a result of the PUCT's order, TNMP recorded a pre-tax write-off of $0.5 million in December 2019.

Transmission Cost of Service Rates

TNMP can update its transmission cost of service (“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. 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)
October 7, 2020	$	10.8	$	2.0
March 12, 2021	$	112.6	$	14.1
September 20, 2021	$	41.2	$	6.3

Periodic Distribution Rate Adjustment

PUCT rules permit interim rate adjustments to reflect changes in investments in distribution assets. Distribution utilities may file for a periodic rate adjustment between April 1 and April 8 of each year as long as the electric utility is not earning more than its authorized rate of return using weather-normalized data.

On April 6, 2020, TNMP filed its 2020 DCOS that requested an increase in TNMP's annual distribution revenue requirement of $14.7 million based on net incremental rate base of $149.2 million. On June 26, 2020, the parties filed a unanimous settlement for a $14.3 million annual distribution revenue requirement with rates effective September 1, 2020. On August 13, 2020, the PUCT approved the unanimous settlement. On April 5, 2021, TNMP filed its 2021 DCOS that requested an increase in TNMP annual distribution revenue requirement of $14.0 million based on an increase in rate base of $104.5 million. On July 1, 2021, TNMP reached a unanimous settlement agreement with parties that would authorize TNMP to collect an increase in annual distribution revenues of $13.5 million beginning in September 2021. Subsequently, the ALJ issued an order on July 9, 2021 approving interim rates effective September 1, 2021, and remanded the case to the PUCT for approval. On September 23, 2021, the PUCT approved substantially all costs in the unanimous settlement.

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 and over collected costs from prior years, rate case expenses, and performance bonuses (if programs exceed mandated savings goals). TNMP’s 2019 EECRF filing requested recovery of $5.9 million, including a performance bonus of $0.8 million, and became effective on March 1, 2020. TNMP’s 2020 EECRF filing requested recovery of $5.9 million, including a performance bonus of $1.0 million, and became effective on March 1, 2021. On May 27, 2021, TNMP filed its request to adjust the EECRF to reflect changes in costs for 2022. The total amount requested was $7.2 million, which includes a performance bonus of $2.3 million based on TNMP's energy efficiency achievements in the 2020 plan year. On July 28, 2021, a unanimous stipulation and settlement was filed with the PUCT to recover its requested costs in 2022, including the performance bonus of $2.3 million. On October 7, 2021, the PUCT approved TNMP's energy efficiency application.

COVID-19 Electricity Relief Program

On March 26, 2020, the PUCT issued an order establishing an 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 ensure these customers continued to have electric service. In addition, the program provided transmission and distribution providers access to zero-interest loans from ERCOT. Collectively, ERCOT’s loans could not exceed $15 million. The program had a term of six months unless extended by the PUCT. In a separate order, the PUCT authorized

electric utilities to establish a regulatory asset for costs related to COVID-19. These costs included but were not limited to costs related to unpaid accounts.

TNMP filed its rider on March 30, 2020. The rider was effective immediately and established a charge of $0.33 per MWh in accordance with the PUCT's order. Final collections under the rider exceeded unpaid residential retail customer bills and were presented net as a regulatory liability of $0.1 million on the Condensed Consolidated Balance Sheet as of December 31, 2020. Other COVID-19 related costs of $0.9 million and $0.7 million were also recorded as a regulatory asset on the Condensed Consolidated Balance Sheet as of September 30, 2021 and December 31, 2020. On April 14, 2020, TNMP executed an interest-free loan agreement to borrow $0.5 million from ERCOT and on October 30, 2020, the balance of the loan was repaid.

On August 27, 2020, the PUCT issued an order determining that new enrollments in the program should end on August 31, 2020, and benefits under the program should end on September 30, 2020, to allow eligible customers a minimum of one month of benefits from the program. All requests for reimbursement were made by November 30, 2020. On December 4, 2020, TNMP filed to end collections under the tariff. Final collections under the rider were made on December 11, 2020. On January 14, 2021, TNMP made a final compliance filing for the electricity relief program.

Advanced Meter System Deployment

TNMP was notified by its largest AMS service provider that its existing communication platform would be decommissioned in February 2022. TNMP evaluated technological alternatives for its AMS and on October 2, 2020, filed an application with the PUCT for authorization to implement necessary upgrades of approximately $46 million by November 2022. On January 14, 2021, the PUCT approved TNMP's application, TNMP will seek recovery of the investment associated with the upgrade in a future general rate proceeding or distribution cost recovery factor filing.

AMS Reconciliation

On July 14, 2021, TNMP filed a request with the PUCT to consider and approve its final reconciliation of the costs spent on the deployment of AMS from April 1, 2018 through December 31, 2018 of $9.0 million and approve appropriate carrying charges until full collection. On September 13, 2021, the PUCT Staff filed a recommendation for approval of TNMP's application for substantially all costs from April 1, 2018 through December 31, 2018.

XML

Lease Commitments

9 Months Ended

Sep. 30, 2021

Leases [Abstract]

Lease Commitments

Lease Commitments

The Company leases office buildings, vehicles, and other equipment. In addition, PNM leases interests in PVNGS Units 1 and 2 and certain rights-of-way agreements are classified as leases. All of the Company's leases with terms in excess of one year are recorded on the balance sheet 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 Condensed Consolidated Statements of Earnings.

See additional discussion of the Company's leasing activities in Note 8 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

PVNGS

PNM leases interests in Units 1 and 2 of PVNGS. The PVNGS leases were entered into in 1985 and 1986 and initially were scheduled to expire on January 15, 2015 for the four Unit 1 leases and January 15, 2016 for the 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 now expire on January 15, 2023 and the one Unit 2 lease now expires on January 15, 2024. The annual lease payments during the renewal periods aggregate $16.5 million for PVNGS Unit 1 and $1.6 million for Unit 2.

The terms of each of the extended leases do not provide for additional renewal options beyond their currently scheduled expiration dates. PNM had the option to purchase the assets underlying each of the extended leases at their fair market value or to return the lease interests to the lessors on the expiration dates. On June 11, 2020, PNM provided notice to the lessors and the

NMPRC of its intent to return the assets underlying both the PVNGS Unit 1 and Unit 2 leases upon their expiration in January 2023 and 2024. Although PNM elected to return the assets underlying the extended leases, PNM retains certain obligations related to PVNGS, including costs to decommission the facility. PNM is depreciating its capital improvements related to the extended leases using NMPRC approved rates through the end of the NRC license period for each unit, which expire in June 2045 for Unit 1 and in June 2046 for Unit 2. On April 5, 2021, PNM and SRP entered into an Asset Purchase and Sale Agreement, pursuant to which PNM agreed to sell to SRP certain PNM-owned assets and nuclear fuel necessary to the ongoing operation and maintenance of leased capacity in PVNGS Unit 1 and Unit 2, which SRP has agreed to acquire from the lessors upon termination of the existing leases. The proposed transaction between PNM and SRP is subject to receipt by PNM of approval by the NMPRC and PNM and SRP require NRC approval for the transfer of the associated possessory licenses at the end of the term of each of the respective leases. If the proposed transaction is not consummated, PNM may be required to retain all or a portion of its currently leased capacity in PVNGS or be exposed to other claims for damages by the lessors. PNM will seek to recover its undepreciated investments, as well as any other obligations related to PVNGS from NM retail customers. See PVNGS Leased Interest Abandonment Application discussion in Note 12.

PNM is exposed to loss under the PVNGS lease arrangements upon the occurrence of certain events that PNM does not consider reasonably likely to occur. Under certain circumstances (for example, the NRC issuing specified violation orders with respect to PVNGS or the occurrence of specified nuclear events), PNM would be required to make specified payments to the lessors and take title to the Leased Interests. If such an event had occurred as of September 30, 2021, amounts due to the lessors under the circumstances described above would be up to $148.4 million, payable on January 15, 2022 in addition to the scheduled lease payments due on that date.

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 2021 payment for the amount due under the Navajo Nation right-of-way lease was $7.3 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 Condensed Consolidated Balance Sheets and recognizes amortization expense associated with these agreements in the Condensed Consolidated Statement of Earnings over their term. As of September 30, 2021 and December 31, 2020, the unamortized balance of these rights-of-ways was $54.0 million and $55.8 million. PNM recognized amortization expense associated with these agreements of $0.9 million and $2.8 million in the three and nine months ended September 30, 2021 and $0.9 million and $2.8 million in the three and nine months ended September 30, 2020.

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 September 30, 2021, residual value guarantees on fleet vehicle and equipment leases are $0.8 million, $1.5 million, and $2.3 million for PNM, TNMP, and PNMR Consolidated.

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

	September 30, 2021						December 31, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating leases:
Operating lease assets, net of amortization	$	79,808	$	5,778	$	85,956	$	97,461	$	7,206	$	105,133
Current portion of operating lease liabilities	26,166		1,988		28,230		25,130		2,193		27,460
Long-term portion of operating lease liabilities	51,233		3,579		55,106		75,941		4,779		81,065

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 Condensed Consolidated Balance Sheets is presented below:

	September 30, 2021						December 31, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Financing leases:
Non-utility property	$	14,276	$	15,722	$	30,328	$	11,453	$	13,299	$	25,055
Accumulated depreciation	(3,838)		(4,185)		(8,185)		(2,044)		(2,241)		(4,383)
Non-utility property, net	10,438		11,537		22,143		9,409		11,058		20,672
Other current liabilities	2,620		2,897		5,602		1,993		2,397		4,470
Other deferred credits	7,639		8,649		16,373		7,176		8,669		15,972

Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities as of September 30, 2021 is presented below:

	PNM		TNMP		PNMR Consolidated
Weighted average remaining lease term (years):
Operating leases	5.83		3.08		5.65
Financing leases	4.31		4.35		4.32
Weighted average discount rate:
Operating leases	3.99	%	3.97	%	3.98	%
Financing leases	2.62	%	2.72	%	2.67	%

Information for the components of lease expense is as follows:

	Three Months Ended September 30, 2021						Nine Months Ended September 30, 2021
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating lease cost:	$	6,569	$	594	$	7,192	$	20,020	$	1,880	$	22,006
Amounts capitalized	(199)		(517)		(716)		(645)		(1,618)		(2,264)
Total operating lease expense	6,370		77		6,476		19,375		262		19,742
Financing lease cost:
Amortization of right-of-use assets	657		693		1,372		1,793		1,944		3,802
Interest on lease liabilities	66		78		145		193		230		426
Amounts capitalized	(452)		(709)		(1,161)		(1,235)		(1,967)		(3,202)
Total financing lease expense	271		62		356		751		207		1,026
Variable lease expense	106		—		106		274		—		274
Short-term lease expense (1)	1,572		2		1,578		1,821		6		1,857
Total lease expense for the period	$	8,319	$	141	$	8,516	$	22,221	$	475	$	22,899

(1) Includes expense of $1.4 million for the three and nine months ended September 30, 2021 for rental of temporary cooling towers associated with the SJGS Unit 1 outage. These amounts are partially offset with insurance reimbursements of $0.9 million for the three and nine months ended September 30, 2021. For additional information on the SJGS Unit 1 outage see Note 12.

	Three Months Ended September 30, 2020						Nine Months Ended September 30, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating lease cost:	$	6,798	$	685	$	7,545	$	20,538	$	2,205	$	22,938
Amounts capitalized	(248)		(577)		(825)		(786)		(1,812)		(2,599)
Total operating lease expense	6,550		108		6,720		19,752		393		20,339
Financing lease cost:
Amortization of right-of-use assets	435		439		893		1,022		1,110		2,187
Interest on lease liabilities	58		74		134		156		198		358
Amounts capitalized	(281)		(452)		(733)		(682)		(1,105)		(1,787)
Total financing lease expense	212		61		294		496		203		758
Variable lease expense	63		—		63		158		—		158
Short-term lease expense	16		4		22		176		5		183
Total lease expense for the period	$	6,841	$	173	$	7,099	$	20,582	$	601	$	21,438

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

	Nine Months Ended						Nine Months Ended
	September 30, 2021						September 30, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	25,511	$	262	$	25,897	$	25,804	$	483	$	26,708
Operating cash flows from financing leases	65		24		92		58		32		94
Finance cash flows from financing leases	621		234		920		378		215		646
Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	—	$	317	$	317	$	—	$	—	$	—
Financing leases	2,898		2,642		5,567		5,635		6,309		11,985

For the nine months ended September 30, 2021, capitalized costs excluded from the operating and financing cash paid for leases above are $0.6 million and $1.2 million at PNM, $1.6 million and $2.0 million at TNMP, and $2.3 million and $3.2 million at PNMR. For the nine months ended September 30, 2020, capitalized costs excluded from the operating and financing cash paid for leases above are $0.8 million and $0.7 million at PNM, $1.8 million and $1.1 million at TNMP, and $2.6 million and $1.8 million at PNMR. These capitalized costs are reflected as investing activities on the Company’s Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2021 and 2020.

Future expected lease payments are shown below:

	As of September 30, 2021
	PNM				TNMP				PNMR Consolidated
	Financing		Operating		Financing		Operating		Financing		Operating
	(In thousands)
Remainder of 2021	$	709	$	334	$	800	$	538	$	1,532	$	935
2022	2,767		26,266		3,125		1,990		5,980		28,467
2023	2,649		17,735		2,906		1,750		5,607		19,665
2024	1,972		7,908		2,438		877		4,421		8,833
2025	1,164		6,946		1,545		702		2,710		7,685
Later years	1,335		27,520		1,417		76		2,752		27,816
Total minimum lease payments	10,596		86,709		12,231		5,933		23,002		93,401
Less: Imputed interest	337		9,310		685		366		1,027		10,065
Lease liabilities as of September 30, 2021	$	10,259	$	77,399	$	11,546	$	5,567	$	21,975	$	83,336

The above table includes $11.3 million, $15.0 million, and $26.3 million for PNM, TNMP, and PNMR at September 30, 2021 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. The Company’s contractual commitments for leases that have not yet commenced are insignificant.

Lease Commitments

Lease Commitments

The Company leases office buildings, vehicles, and other equipment. In addition, PNM leases interests in PVNGS Units 1 and 2 and certain rights-of-way agreements are classified as leases. All of the Company's leases with terms in excess of one year are recorded on the balance sheet 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 Condensed Consolidated Statements of Earnings.

See additional discussion of the Company's leasing activities in Note 8 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

PVNGS

PNM leases interests in Units 1 and 2 of PVNGS. The PVNGS leases were entered into in 1985 and 1986 and initially were scheduled to expire on January 15, 2015 for the four Unit 1 leases and January 15, 2016 for the 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 now expire on January 15, 2023 and the one Unit 2 lease now expires on January 15, 2024. The annual lease payments during the renewal periods aggregate $16.5 million for PVNGS Unit 1 and $1.6 million for Unit 2.

The terms of each of the extended leases do not provide for additional renewal options beyond their currently scheduled expiration dates. PNM had the option to purchase the assets underlying each of the extended leases at their fair market value or to return the lease interests to the lessors on the expiration dates. On June 11, 2020, PNM provided notice to the lessors and the

NMPRC of its intent to return the assets underlying both the PVNGS Unit 1 and Unit 2 leases upon their expiration in January 2023 and 2024. Although PNM elected to return the assets underlying the extended leases, PNM retains certain obligations related to PVNGS, including costs to decommission the facility. PNM is depreciating its capital improvements related to the extended leases using NMPRC approved rates through the end of the NRC license period for each unit, which expire in June 2045 for Unit 1 and in June 2046 for Unit 2. On April 5, 2021, PNM and SRP entered into an Asset Purchase and Sale Agreement, pursuant to which PNM agreed to sell to SRP certain PNM-owned assets and nuclear fuel necessary to the ongoing operation and maintenance of leased capacity in PVNGS Unit 1 and Unit 2, which SRP has agreed to acquire from the lessors upon termination of the existing leases. The proposed transaction between PNM and SRP is subject to receipt by PNM of approval by the NMPRC and PNM and SRP require NRC approval for the transfer of the associated possessory licenses at the end of the term of each of the respective leases. If the proposed transaction is not consummated, PNM may be required to retain all or a portion of its currently leased capacity in PVNGS or be exposed to other claims for damages by the lessors. PNM will seek to recover its undepreciated investments, as well as any other obligations related to PVNGS from NM retail customers. See PVNGS Leased Interest Abandonment Application discussion in Note 12.

PNM is exposed to loss under the PVNGS lease arrangements upon the occurrence of certain events that PNM does not consider reasonably likely to occur. Under certain circumstances (for example, the NRC issuing specified violation orders with respect to PVNGS or the occurrence of specified nuclear events), PNM would be required to make specified payments to the lessors and take title to the Leased Interests. If such an event had occurred as of September 30, 2021, amounts due to the lessors under the circumstances described above would be up to $148.4 million, payable on January 15, 2022 in addition to the scheduled lease payments due on that date.

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 2021 payment for the amount due under the Navajo Nation right-of-way lease was $7.3 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 Condensed Consolidated Balance Sheets and recognizes amortization expense associated with these agreements in the Condensed Consolidated Statement of Earnings over their term. As of September 30, 2021 and December 31, 2020, the unamortized balance of these rights-of-ways was $54.0 million and $55.8 million. PNM recognized amortization expense associated with these agreements of $0.9 million and $2.8 million in the three and nine months ended September 30, 2021 and $0.9 million and $2.8 million in the three and nine months ended September 30, 2020.

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 September 30, 2021, residual value guarantees on fleet vehicle and equipment leases are $0.8 million, $1.5 million, and $2.3 million for PNM, TNMP, and PNMR Consolidated.

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

	September 30, 2021						December 31, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating leases:
Operating lease assets, net of amortization	$	79,808	$	5,778	$	85,956	$	97,461	$	7,206	$	105,133
Current portion of operating lease liabilities	26,166		1,988		28,230		25,130		2,193		27,460
Long-term portion of operating lease liabilities	51,233		3,579		55,106		75,941		4,779		81,065

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 Condensed Consolidated Balance Sheets is presented below:

	September 30, 2021						December 31, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Financing leases:
Non-utility property	$	14,276	$	15,722	$	30,328	$	11,453	$	13,299	$	25,055
Accumulated depreciation	(3,838)		(4,185)		(8,185)		(2,044)		(2,241)		(4,383)
Non-utility property, net	10,438		11,537		22,143		9,409		11,058		20,672
Other current liabilities	2,620		2,897		5,602		1,993		2,397		4,470
Other deferred credits	7,639		8,649		16,373		7,176		8,669		15,972

Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities as of September 30, 2021 is presented below:

	PNM		TNMP		PNMR Consolidated
Weighted average remaining lease term (years):
Operating leases	5.83		3.08		5.65
Financing leases	4.31		4.35		4.32
Weighted average discount rate:
Operating leases	3.99	%	3.97	%	3.98	%
Financing leases	2.62	%	2.72	%	2.67	%

Information for the components of lease expense is as follows:

	Three Months Ended September 30, 2021						Nine Months Ended September 30, 2021
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating lease cost:	$	6,569	$	594	$	7,192	$	20,020	$	1,880	$	22,006
Amounts capitalized	(199)		(517)		(716)		(645)		(1,618)		(2,264)
Total operating lease expense	6,370		77		6,476		19,375		262		19,742
Financing lease cost:
Amortization of right-of-use assets	657		693		1,372		1,793		1,944		3,802
Interest on lease liabilities	66		78		145		193		230		426
Amounts capitalized	(452)		(709)		(1,161)		(1,235)		(1,967)		(3,202)
Total financing lease expense	271		62		356		751		207		1,026
Variable lease expense	106		—		106		274		—		274
Short-term lease expense (1)	1,572		2		1,578		1,821		6		1,857
Total lease expense for the period	$	8,319	$	141	$	8,516	$	22,221	$	475	$	22,899

(1) Includes expense of $1.4 million for the three and nine months ended September 30, 2021 for rental of temporary cooling towers associated with the SJGS Unit 1 outage. These amounts are partially offset with insurance reimbursements of $0.9 million for the three and nine months ended September 30, 2021. For additional information on the SJGS Unit 1 outage see Note 12.

	Three Months Ended September 30, 2020						Nine Months Ended September 30, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating lease cost:	$	6,798	$	685	$	7,545	$	20,538	$	2,205	$	22,938
Amounts capitalized	(248)		(577)		(825)		(786)		(1,812)		(2,599)
Total operating lease expense	6,550		108		6,720		19,752		393		20,339
Financing lease cost:
Amortization of right-of-use assets	435		439		893		1,022		1,110		2,187
Interest on lease liabilities	58		74		134		156		198		358
Amounts capitalized	(281)		(452)		(733)		(682)		(1,105)		(1,787)
Total financing lease expense	212		61		294		496		203		758
Variable lease expense	63		—		63		158		—		158
Short-term lease expense	16		4		22		176		5		183
Total lease expense for the period	$	6,841	$	173	$	7,099	$	20,582	$	601	$	21,438

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

	Nine Months Ended						Nine Months Ended
	September 30, 2021						September 30, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	25,511	$	262	$	25,897	$	25,804	$	483	$	26,708
Operating cash flows from financing leases	65		24		92		58		32		94
Finance cash flows from financing leases	621		234		920		378		215		646
Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	—	$	317	$	317	$	—	$	—	$	—
Financing leases	2,898		2,642		5,567		5,635		6,309		11,985

For the nine months ended September 30, 2021, capitalized costs excluded from the operating and financing cash paid for leases above are $0.6 million and $1.2 million at PNM, $1.6 million and $2.0 million at TNMP, and $2.3 million and $3.2 million at PNMR. For the nine months ended September 30, 2020, capitalized costs excluded from the operating and financing cash paid for leases above are $0.8 million and $0.7 million at PNM, $1.8 million and $1.1 million at TNMP, and $2.6 million and $1.8 million at PNMR. These capitalized costs are reflected as investing activities on the Company’s Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2021 and 2020.

Future expected lease payments are shown below:

	As of September 30, 2021
	PNM				TNMP				PNMR Consolidated
	Financing		Operating		Financing		Operating		Financing		Operating
	(In thousands)
Remainder of 2021	$	709	$	334	$	800	$	538	$	1,532	$	935
2022	2,767		26,266		3,125		1,990		5,980		28,467
2023	2,649		17,735		2,906		1,750		5,607		19,665
2024	1,972		7,908		2,438		877		4,421		8,833
2025	1,164		6,946		1,545		702		2,710		7,685
Later years	1,335		27,520		1,417		76		2,752		27,816
Total minimum lease payments	10,596		86,709		12,231		5,933		23,002		93,401
Less: Imputed interest	337		9,310		685		366		1,027		10,065
Lease liabilities as of September 30, 2021	$	10,259	$	77,399	$	11,546	$	5,567	$	21,975	$	83,336

The above table includes $11.3 million, $15.0 million, and $26.3 million for PNM, TNMP, and PNMR at September 30, 2021 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. The Company’s contractual commitments for leases that have not yet commenced are insignificant.

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Income Taxes

9 Months Ended

Sep. 30, 2021

Income Tax Disclosure [Abstract]

Income Taxes

Income TaxesIn December 2017, comprehensive changes in United States 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. In addition, in 2019, the IRS issued regulations interpreting Tax Act amendments to depreciation provisions of the IRC that allow the Company to claim a bonus depreciation deduction on certain construction projects placed in service subsequent to the third quarter of 2017. See additional discussion of the impacts of the Tax Act in Note 18 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K. On March 27, 2020, the Coronavirus Aid, Relief and Economic Security Act (the “CARES Act”) was enacted. Among other things, the CARES Act includes tax provisions that generally loosen restrictions on NOL utilization and business interest deductions, and accelerate refunds of previously generated alternative minimum tax credits. In addition, the CARES Act includes a temporary provision allowing businesses to defer payments to the government for some payroll taxes. In 2020, the Company applied for $5.2 million of accelerated refunds of previously generated alternative minimum tax ("AMT") credits and deferred $7.0 million of payments for certain payroll taxes. The Company received the $5.2 million refund of prior AMT credits in June 2021. The CARES Act provisions related to NOL utilization and business interest deductions are not applicable for the Company.

Beginning February 2018, PNM’s NM 2016 Rate Case reflects the reduction in the federal corporate income tax rate, including amortization of excess deferred federal and state income taxes. In accordance with the order in that case, 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, and the unprotected portion of excess deferred federal income taxes to customers over a period of approximately twenty-three years. 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. PNMR, PNM, and TNMP will amortize federal and state excess deferred income taxes of $24.5 million, $15.2 million, and $9.3 million in 2021. See additional discussion of PNM’s NM 2016 Rate Case and TNMP’s 2018 Rate Case in Note 17 of the Notes to Consolidated Financial Statements in the 2020 Annual Reports on Form 10-K.

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 income taxes. Certain unusual or infrequently occurring items, including excess tax benefits related to stock awards and taxes on Merger-related costs are excluded from the estimated annual effective tax rate calculation. At September 30, 2021, PNMR, PNM, and TNMP estimated their effective income tax rates for the year ended December 31, 2021 would be 13.08%, 15.43%, and 11.12%. The primary difference between the statutory income tax rates and the effective tax rates is the effect of the reduction in income tax expense resulting from the amortization of excess deferred federal income taxes. During the three and nine months ended September 30, 2021, income tax expense calculated by applying the expected annual effective income tax rate to earnings before income taxes was further reduced by excess tax benefits related to stock awards of less than $0.1 million and $0.8 million for PNMR, of which less than $0.1 million and $0.6 million was allocated to PNM and less than $0.1 million and $0.2 million was allocated to TNMP, and by tax benefits on Merger-related costs of $0.3 million and $1.8 million for PNMR, less than $0.1 million and $0.1 million for PNM, and less than $0.1 million and $0.1 million for TNMP.

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Related Party Transactions

9 Months Ended

Sep. 30, 2021

Related Party Transactions [Abstract]

Related Party Transactions

Related Party TransactionsPNMR, PNM, TNMP, and NMRD are considered related parties, as is PNMR Services Company, a wholly-owned subsidiary of PNMR that provides corporate services to PNMR 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, PNMR provides construction and operations and maintenance services to NMRD, a 50% owned subsidiary of PNMR Development. PNM purchases renewable energy from certain NMRD-owned facilities at a fixed price per MWh of energy produced. PNM also provides interconnection services to PNMR Development and NMRD. See Note 16 for additional discussion of NMRD.

The table below summarizes the nature and amount of related party transactions of PNMR, PNM, TNMP, and NMRD:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands)
Services billings:
PNMR to PNM	$	23,617	$	24,204	$	75,992	$	70,848
PNMR to TNMP	9,187		9,645		29,687		28,075
PNM to TNMP	107		106		319		295
TNMP to PNMR	—		35		24		106
PNMR to NMRD	55		74		165		199
Renewable energy purchases:
PNM from NMRD	3,384		3,723		9,473		7,646
Interconnection billings:
PNM to NMRD	225		—		225		350
PNM to PNMR	—		—		—		—
NMRD to PNM	—		—		1,276		—
Interest billings:
PNMR to PNM	—		—		—		6
PNM to PNMR	36		60		108		218
PNMR to TNMP	—		—		—		2
Income tax sharing payments:
PNMR to PNM	—		—		—		—
TNMP to PNMR	—		—		—		—

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Equity Method Investment

9 Months Ended

Sep. 30, 2021

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investment

Equity Method Investment

As discussed in Note 1 of the Company's 2020 Annual Reports on Form 10-K, PNMR Development and AEP OnSite Partners created NMRD in September 2017 to pursue the acquisition, development, and ownership of renewable energy generation projects, primarily in the state of New Mexico. As of September 30, 2021, NMRD’s renewable energy capacity in operation was 135.1 MW. PNMR Development and AEP OnSite Partners each have a 50% ownership interest in NMRD. The investment in NMRD is accounted for using the equity method of accounting because PNMR’s ownership interest results in significant influence, but not control, over NMRD and its operations.

In the nine months ended September 30, 2021 and 2020, PNMR Development made cash contributions of zero and $23.3 million to NMRD to be used primarily for its construction activities. In February 2021, NMRD paid PNMR Development a dividend of $3.0 million of which, $2.4 million represented PNMR Development's cumulative equity in earnings of NMRD as of March 31, 2021 and is presented as cash flows from operating activities on the Condensed Consolidated Statement of Cash Flows for the nine months ended September 30, 2021. The portion of the dividend in excess of PNMR Development's cumulative equity in earnings of NMRD amounting to $0.6 million is presented as cash flows from investing activities.

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

	Results of Operations
	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands)
Operating revenues	$	3,543	$	3,462	$	10,179	$	7,769
Operating expenses	2,422		2,100		7,360		5,152
Net earnings	$	1,121	$	1,362	$	2,819	$	2,617

	Financial Position
	September 30,		December 31,
	2021		2020
	(In thousands)
Current assets	$	9,164	$	8,046
Net property, plant, and equipment	168,053		172,585
Non-current assets	2,448		1,900
Total assets	179,665		182,531
Current liabilities	1,166		841
Non-current liabilities	370		380
Owners’ equity	$	178,129	$	181,310

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Goodwill

9 Months Ended

Sep. 30, 2021

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill

Goodwill

The excess purchase price over the fair value of the assets acquired and the liabilities assumed by PNMR 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. PNMR’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 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.

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

For its annual evaluations performed as of April 1, 2020, PNMR performed a qualitative analysis for the PNM reporting unit and a quantitative analysis for the TNMP reporting unit. In addition to the typical considerations discussed above, the qualitative analysis considered changes in PNM’s expectations of future financial performance since the April 1, 2018 quantitative analysis performed for PNM, as well as the previous qualitative analyses through April 1, 2019. The April 1, 2018 quantitative evaluations indicated the fair value of the PNM reporting unit, which has goodwill of $51.6 million, exceeded its carrying value by approximately 19%. Based on an evaluation of these and other factors, the Company determined it was not more likely than not that the April 1, 2020 carrying value of PNM exceeded its fair value. Using the methods and considerations discussed above, the 2020 quantitative analysis indicated the fair value of the TNMP reporting unit, which has goodwill of $226.7 million, exceeded its carrying value by approximately 38%. Based on an evaluation of these and other factors, the Company determined it was not more likely than not that the April 1, 2020 carrying value of TNMP exceeded its fair value.

For its annual evaluations performed as of April 1, 2021, PNMR 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, 2020 qualitative analysis for PNM and the quantitative analysis for TNMP. This analysis considered Company specific events such as the Merger, potential impacts of legal and regulatory matters discussed in Note 11 and Note 12, including potential outcomes in PNM’s Four Corners 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, 2021 carrying values of PNM and TNMP exceeded their fair value. Since the April 1, 2021 annual evaluation, there have been no events, including the Merger (Note 18), or indications that the fair values of the reporting units with recorded goodwill have decreased below their carrying values.

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Merger

9 Months Ended

Sep. 30, 2021

Business Combinations [Abstract]

Merger

Merger

On October 20, 2020, PNMR, Avangrid, and Merger Sub, entered into the Merger Agreement pursuant to which Merger Sub will merge with and into PNMR, with PNMR surviving the Merger as a wholly-owned subsidiary of Avangrid.

Pursuant to the Merger Agreement, each issued and outstanding share of the common stock of PNMR (other than (i) the issued shares of PNMR common stock that are owned by Avangrid, Merger Sub, PNMR or any wholly-owned subsidiary of Avangrid or PNMR, which will be automatically cancelled at the time the Merger is consummated (the "Effective Time") and (ii) shares of PNMR common stock outstanding immediately prior to the Effective Time and held by a holder who has not voted in favor of, or consented in writing to, the Merger who is entitled to, and who has demanded, payment for fair value of such shares) will be converted into the right to receive $50.30 in cash.

The proposed Merger has been unanimously approved by the Boards of Directors of PNMR, Avangrid and Merger Sub and approved by PNMR shareholders at the Special Meeting of Shareholders held on February 12, 2021. On January 20, 2021, the FTC notified PNMR and Avangrid that early termination of the waiting period under the HSR Act in connection with the Merger was granted. CFIUS completed its review of the Merger on February 2, 2021, and has concluded that there are no unresolved national security concerns with respect to the Merger. On March 10, 2021, PNMR and Avangrid received FCC approval of the transfer of operating licenses related to the Merger. On April 20, 2021, FERC issued an order authorizing the Merger. On May 6, 2021, the PUCT issued an order authorizing the Merger, and on May 25, 2021, the NRC approved the Merger. Consummation of the Merger remains subject to the satisfaction or waiver of certain customary closing conditions, including, without limitation, the absence of any material adverse effect on PNMR, the receipt of required regulatory approval from the NMPRC, and the agreements relating to the divestiture of Four Corners being in full force and effect and all applicable regulatory filings associated therewith being made. The agreement related to the divestiture has been entered into and related filings have been made with the NMPRC. The Merger is currently expected to close in the fourth quarter of 2021.

On April 20, 2021, the Joint Applicants, the NMAG, WRA, the International Brotherhood of Electrical Workers Local 611, Dine, Nava Education Project, the San Juan Citizens Alliance and To Nizhoni Ani, entered into a stipulation and

agreement in the Joint Application for approval of Merger pending before the NMPRC. Subsequently, CCAE, Onward Energy, Walmart, Interwest Energy Alliance, M-S-R Power and the Incorporated County of Los Alamos have joined an amended stipulation. An evidentiary hearing was held from August 11 - 19, 2021. Post hearing briefs were filed on September 21, 2021 and response briefs were filed on September 28, 2021.

The Merger Agreement provides for certain customary termination rights including the right of either party to terminate the Merger Agreement if the Merger is not completed on or before January 20, 2022 (subject to a three-month extension by either party if all of the conditions to the closing, other than the conditions related to obtaining regulatory approvals, have been satisfied or waived). The Merger Agreement further provides that, upon termination of the Merger Agreement under certain specified circumstances (including if Avangrid terminates the Merger Agreement due to a change in recommendation of the Board or if PNMR terminates the Merger Agreement to accept a superior proposal (as defined in the Merger Agreement)), PNMR will be required to pay Avangrid a termination fee of $130.0 million. In addition, the Merger Agreement provides that (i) if the Merger Agreement is terminated by either party due to a failure of a regulatory closing condition and such failure is the result of Avangrid’s breach of its regulatory covenants or (ii) Avangrid fails to effect the closing when all closing conditions have been satisfied and it is otherwise obligated to do so under the Merger Agreement, then, in either such case, upon termination of the Merger Agreement, Avangrid will be required to pay PNMR a termination fee of $184.0 million as the sole and exclusive remedy. Upon the termination of the Merger Agreement under certain specified circumstances involving a breach of the Merger Agreement, either PNMR or Avangrid will be required to reimburse the other party’s reasonable and documented out-of-pocket fees and expenses up to $10.0 million (which amount will be credited toward, and offset against, the payment of any applicable termination fee).

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Significant Accounting Policies and Responsibility for Financial Statements (Policies)

9 Months Ended

Sep. 30, 2021

Accounting Policies [Abstract]

Principles of Consolidation

Principles of Consolidation

The Condensed Consolidated Financial Statements of each of PNMR, PNM, and TNMP include their accounts and those of subsidiaries in which that entity owns a majority voting interest. PNM also consolidates Valencia. See Note 6. PNM owns undivided interests in several 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 PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as equity transactions, and interconnection billings. See Note 15. All intercompany transactions and balances have been eliminated.

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Segment Information (Tables)

9 Months Ended

Sep. 30, 2021

Segment Reporting [Abstract]

Summary of Financial Information by Segment

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

PNMR SEGMENT INFORMATION

	PNM		TNMP		Corporate and Other		PNMR Consolidated
	(In thousands)
Three Months Ended September 30, 2021
Electric operating revenues	$	435,523	$	119,028	$	—	$	554,551
Cost of energy	170,902		28,478		—		199,380
Utility margin	264,621		90,550		—		355,171
Other operating expenses	107,385		28,677		(4,058)		132,004
Depreciation and amortization	42,673		23,031		5,734		71,438
Operating income (loss)	114,563		38,842		(1,676)		151,729
Interest income (loss)	3,364		—		(35)		3,329
Other income	1,358		1,144		34		2,536
Interest charges	(12,509)		(8,403)		(2,332)		(23,244)
Segment earnings (loss) before income taxes	106,776		31,583		(4,009)		134,350
Income taxes (benefit)	15,500		3,642		(2,474)		16,668
Segment earnings (loss)	91,276		27,941		(1,535)		117,682
Valencia non-controlling interest	(4,229)		—		—		(4,229)
Subsidiary preferred stock dividends	(132)		—		—		(132)
Segment earnings (loss) attributable to PNMR	$	86,915	$	27,941	$	(1,535)	$	113,321
Nine Months Ended September 30, 2021
Electric operating revenues	$	1,030,685	$	315,113	$	—	$	1,345,798
Cost of energy	383,556		83,896		—		467,452
Utility margin	647,129		231,217		—		878,346
Other operating expenses	320,638		82,950		(6,379)		397,209
Depreciation and amortization	127,111		67,696		17,232		212,039
Operating income (loss)	199,380		80,571		(10,853)		269,098
Interest income	10,376		—		90		10,466
Other income (deductions)	13,705		3,251		(92)		16,864
Interest charges	(38,441)		(25,155)		(9,651)		(73,247)
Segment earnings (loss) before income taxes	185,020		58,667		(20,506)		223,181
Income taxes (benefit)	26,178		6,341		(5,986)		26,533
Segment earnings (loss)	158,842		52,326		(14,520)		196,648
Valencia non-controlling interest	(11,643)		—		—		(11,643)
Subsidiary preferred stock dividends	(396)		—		—		(396)
Segment earnings (loss) attributable to PNMR	$	146,803	$	52,326	$	(14,520)	$	184,609
At September 30, 2021:
Total Assets	$	5,723,176	$	2,311,559	$	221,335	$	8,256,070
Goodwill	$	51,632	$	226,665	$	—	$	278,297

	PNM		TNMP		Corporate and Other		PNMR Consolidated
	(In thousands)
Three Months Ended September 30, 2020
Electric operating revenues	$	364,504	$	107,961	$	—	$	472,465
Cost of energy	108,284		25,707		—		133,991
Utility margin	256,220		82,254		—		338,474
Other operating expenses	99,171		27,983		(4,885)		122,269
Depreciation and amortization	40,509		22,492		5,399		68,400
Operating income (loss)	116,540		31,779		(514)		147,805
Interest income	3,239		—		(59)		3,180
Other income	11,563		2,286		213		14,062
Interest charges	(14,747)		(7,942)		(4,574)		(27,263)
Segment earnings (loss) before income taxes	116,595		26,123		(4,934)		137,784
Income taxes (benefit)	13,591		2,202		(3,462)		12,331
Segment earnings (loss)	103,004		23,921		(1,472)		125,453
Valencia non-controlling interest	(3,553)		—		—		(3,553)
Subsidiary preferred stock dividends	(132)		—		—		(132)
Segment earnings (loss) attributable to PNMR	$	99,319	$	23,921	$	(1,472)	$	121,768
Nine Months Ended September 30, 2020
Electric operating revenues	$	873,425	$	290,311	$	—	$	1,163,736
Cost of energy	250,692		75,872		—		326,564
Utility margin	622,733		214,439		—		837,172
Other operating expenses	299,284		78,444		(14,644)		363,084
Depreciation and amortization	123,721		66,696		16,978		207,395
Operating income (loss)	199,728		69,299		(2,334)		266,693
Interest income	9,882		—		(208)		9,674
Other income (deductions)	(1,509)		4,810		(542)		2,759
Interest charges	(51,554)		(22,475)		(14,756)		(88,785)
Segment earnings (loss) before income taxes	156,547		51,634		(17,840)		190,341
Income taxes (benefit)	16,127		4,447		(5,848)		14,726
Segment earnings (loss)	140,420		47,187		(11,992)		175,615
Valencia non-controlling interest	(11,222)		—		—		(11,222)
Subsidiary preferred stock dividends	(396)		—		—		(396)
Segment earnings (loss) attributable to PNMR	$	128,802	$	47,187	$	(11,992)	$	163,997
At September 30, 2020:
Total Assets	$	5,449,238	$	2,075,291	$	217,583	$	7,742,112
Goodwill	$	51,632	$	226,665	$	—	$	278,297

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Accumulated Other Comprehensive Income (Loss) (Tables)

9 Months Ended

Sep. 30, 2021

Equity [Abstract]

Schedule of Accumulated Other Comprehensive Income (Loss)

Information regarding accumulated other comprehensive income (loss) for the nine months ended September 30, 2021 and 2020 is as follows:

	Accumulated Other Comprehensive Income (Loss)
	PNM						Corporate and Other		PNMR Consolidated
	Unrealized Gains on Available-for-Sale Debt Securities		Pension Liability Adjustment				Fair Value Adjustment for Cash Flow Hedges
					Total				Total
	(In thousands)
Balance at December 31, 2020	$	20,403	$	(98,914)	$	(78,511)	$	(672)	$	(79,183)
Amounts reclassified from AOCI (pre-tax)	(8,120)		6,261		(1,859)		(903)		(2,762)
Income tax impact of amounts reclassified	2,062		(1,590)		472		229		701
Other OCI changes (pre-tax)	(968)		—		(968)		1,804		836
Income tax impact of other OCI changes	246		—		246		(458)		(212)
Net after-tax change	(6,780)		4,671		(2,109)		672		(1,437)
Balance at September 30, 2021	$	13,623	$	(94,243)	$	(80,620)	$	—	$	(80,620)

Balance at December 31, 2019	$	10,638	$	(109,693)	$	(99,055)	$	(322)	$	(99,377)
Amounts reclassified from AOCI (pre-tax)	(7,156)		6,225		(931)		(1,117)		(2,048)
Income tax impact of amounts reclassified	1,818		(1,581)		237		284		521
Other OCI changes (pre-tax)	14,750		—		14,750		33		14,783
Income tax impact of other OCI changes	(3,746)		—		(3,746)		(9)		(3,755)
Net after-tax change	5,666		4,644		10,310		(809)		9,501
Balance at September 30, 2020	$	16,304	$	(105,049)	$	(88,745)	$	(1,131)	$	(89,876)

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Earnings Per Share (Tables)

9 Months Ended

Sep. 30, 2021

Earnings Per Share [Abstract]

Computation of Earnings Per Share

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

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands, except per share amounts)
Net Earnings Attributable to PNMR	$	113,321	$	121,768	$	184,609	$	163,997
Average Number of Common Shares:
Outstanding during period	85,835		79,654		85,835		79,654
Vested awards of restricted stock	237		213		230		205
Average Shares – Basic	86,072		79,867		86,065		79,859
Dilutive Effect of Common Stock Equivalents:
PNMR 2020 Forward Equity Sale Agreements	—		—		—		57
Restricted stock	41		39		41		38
Average Shares – Diluted	86,113		79,906		86,106		79,954
Net Earnings Per Share of Common Stock:
Basic	$	1.32	$	1.52	$	2.14	$	2.05
Diluted	$	1.32	$	1.52	$	2.14	$	2.05

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Electric Operating Revenues (Tables)

9 Months Ended

Sep. 30, 2021

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

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

	PNM		TNMP		PNMR Consolidated
Three Months Ended September 30, 2021	(In thousands)
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	155,035	$	51,839	$	206,874
Commercial	137,071		34,434		171,505
Industrial	24,856		7,282		32,138
Public authority	7,388		1,614		9,002
Economy energy service	7,389		—		7,389
Transmission	26,459		24,075		50,534
Miscellaneous	3,503		936		4,439
Total revenues from contracts with customers	361,701		120,180		481,881
Alternative revenue programs	(8,331)		(1,152)		(9,483)
Other electric operating revenues	82,153		—		82,153
Total Electric Operating Revenues	$	435,523	$	119,028	$	554,551
Nine Months Ended September 30, 2021
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	377,794	$	121,600	$	499,394
Commercial	327,090		93,332		420,422
Industrial	66,593		21,621		88,214
Public authority	17,312		4,561		21,873
Economy energy service	24,722		—		24,722
Transmission	60,919		68,849		129,768
Miscellaneous	10,129		2,837		12,966
Total revenues from contracts with customers	884,559		312,800		1,197,359
Alternative revenue programs	(5,469)		2,313		(3,156)
Other electric operating revenues	151,595		—		151,595
Total Electric Operating Revenues	$	1,030,685	$	315,113	$	1,345,798

	PNM		TNMP		PNMR Consolidated
Three Months Ended September 30, 2020	(In thousands)
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	158,549	$	53,114	$	211,663
Commercial	125,414		31,077		156,491
Industrial	25,475		6,842		32,317
Public authority	7,982		1,468		9,450
Economy energy service	3,270		—		3,270
Transmission	17,463		19,845		37,308
Miscellaneous	3,697		924		4,621
Total revenues from contracts with customers	341,850		113,270		455,120
Alternative revenue programs	(7,067)		(5,309)		(12,376)
Other electric operating revenues	29,721		—		29,721
Total Electric Operating Revenues	$	364,504	$	107,961	$	472,465
Nine Months Ended September 30, 2020
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential	$	370,448	$	122,315	$	492,763
Commercial	305,127		87,868		392,995
Industrial	65,313		20,232		85,545
Public authority	17,236		4,311		21,547
Economy energy service	11,802		—		11,802
Transmission	45,727		58,095		103,822
Miscellaneous	10,106		2,597		12,703
Total revenues from contracts with customers	825,759		295,418		1,121,177
Alternative revenue programs	(2,377)		(5,107)		(7,484)
Other electric operating revenues	50,043		—		50,043
Total Electric Operating Revenues	$	873,425	$	290,311	$	1,163,736

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Variable Interest Entities (Tables)

9 Months Ended

Sep. 30, 2021

Variable Interest Entities [Abstract]

Summarized Financial Information

Summarized financial information for Valencia is as follows:

	Results of Operations
	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands)
Operating revenues	$	5,719	$	5,278	$	16,425	$	16,126
Operating expenses	1,490		1,725		4,782		4,904
Earnings attributable to non-controlling interest	$	4,229	$	3,553	$	11,643	$	11,222

	Financial Position
	September 30,		December 31,
	2021		2020
	(In thousands)
Current assets	$	3,981	$	3,911
Net property, plant, and equipment	53,617		55,744
Total assets	57,598		59,655
Current liabilities	1,184		646
Owners’ equity – non-controlling interest	$	56,414	$	59,009

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Fair Value of Derivative and Other Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2021

Fair Value of Derivative and Other Financial Instruments [Abstract]

Summary of 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 Condensed Consolidated Balance Sheets:

	Economic Hedges
	September 30, 2021		December 31, 2020
	(In thousands)
Other current assets	$	753	$	1,096
Other deferred charges	—		455
	753		1,551
Other current liabilities	(2,703)		(1,096)
Other deferred credits	—		(455)
	(2,703)		(1,551)
Net	$	(1,950)	$	—

Schedule of Gross Realized Gains and Losses

Gains and losses recognized on the Condensed Consolidated Statements of Earnings related to investment securities in the NDT and reclamation trusts are presented in the following table:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands)
Equity securities:
Net gains (losses) from equity securities sold	$	(309)	$	90	$	5,931	$	4,131
Net gains (losses) from equity securities still held	(3,153)		8,545		2,388		2,991
Total net gains (losses) on equity securities	(3,462)		8,635		8,319		7,122
Available-for-sale debt securities:
Net gains (losses) on debt securities	5,410		5,766		7,789		(3,950)
Net gains on investment securities	$	1,948	$	14,401	$	16,108	$	3,172

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 $0.6 million and $1.2 million for the three and nine months ended September 30, 2021 and $4.2 million and $(4.5) million for the three and nine months ended September 30, 2020.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands)
Proceeds from sales	$	128,683	$	134,567	$	396,870	$	489,218
Gross realized gains	$	10,986	$	12,998	$	30,290	$	30,085
Gross realized (losses)	$	(6,527)	$	(11,374)	$	(17,776)	$	(25,411)

Investments Classified by Contractual Maturity Date

At September 30, 2021, the available-for-sale debt securities held by PNM, had the following final maturities:

	Fair Value
	(In thousands)
Within 1 year	$	26,085
After 1 year through 5 years	77,703
After 5 years through 10 years	93,532
After 10 years through 15 years	21,475
After 15 years through 20 years	13,858
After 20 years	33,306
	$	265,959

Schedule of Investments

Items recorded at fair value by PNM on the Condensed 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)
September 30, 2021
Cash and cash equivalents	$	8,229	$	8,229	$	—
Equity securities:
Corporate stocks, common	99,681		99,681		—
Corporate stocks, preferred	9,046		3,256		5,790
Mutual funds and other	72,494		72,404		90
Available-for-sale debt securities:
U.S. government	44,408		14,914		29,494		$	270
International government	16,925		—		16,925		1,782
Municipals	47,860		—		47,860		1,896
Corporate and other	156,766		—		156,766		14,351
	$	455,409	$	198,484	$	256,925	$	18,299

	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Unrealized Gains
	(In thousands)
December 31, 2020
Cash and cash equivalents	$	6,107	$	6,107	$	—
Equity securities:
Corporate stocks, common	85,271		85,271		—
Corporate stocks, preferred	9,910		3,608		6,302
Mutual funds and other	58,817		58,762		55
Available-for-sale debt securities:
U.S. government	55,839		29,579		26,260		$	950
International government	16,032		—		16,032		2,537
Municipals	50,139		—		50,139		2,779
Corporate and other	158,000		3		157,997		21,121
	$	440,115	$	183,330	$	256,785	$	27,387

Schedule of Carrying Amount and Fair Value of Items Not Recorded at Fair Value

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 Condensed Consolidated Balance Sheets, are presented below:

	Carrying Amount		Fair Value
September 30, 2021	(In thousands)
PNMR	$	3,500,233	$	3,724,723
PNM	$	1,732,442	$	1,834,677
TNMP	$	918,074	$	1,040,046
December 31, 2020
PNMR	$	3,295,150	$	3,355,761
PNM	$	1,696,620	$	1,602,547
TNMP	$	853,673	$	1,006,722

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Stock-Based Compensation (Tables)

9 Months Ended

Sep. 30, 2021

Share-based Payment Arrangement [Abstract]

Summary of Activity

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

	Nine Months Ended September 30,
Restricted Shares and Performance Based Shares	2021			2020
Expected quarterly dividends per share	$	0.3275		$	0.3075
Risk-free interest rate	0.32		%	0.72		%
Market-Based Shares
Dividend yield	2.76		%	2.51		%
Expected volatility	33.69		%	19.41		%
Risk-free interest rate	0.29		%	0.72		%

The following table summarizes activity in restricted stock awards, including performance-based and market-based shares for the nine months ended September 30, 2021:

	Restricted Stock
	Shares	Weighted- Average Grant Date Fair Value
Outstanding at December 31, 2020	168,061	$	40.77
Granted	213,515	43.48
Exercised	(210,572)	40.73
Forfeited	(1,741)	43.72
Outstanding at September 30, 2021	169,263	$	43.71

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

	Nine Months Ended September 30,
Restricted Stock	2021		2020
Weighted-average grant date fair value	$	43.48	$	36.73
Total fair value of restricted shares that vested (in thousands)	$	10,018	$	11,740
Stock Options
Total intrinsic value of options exercised (in thousands)	$	—	$	84

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Financing (Tables)

9 Months Ended

Sep. 30, 2021

Debt Disclosure [Abstract]

Schedule of Short-term Debt

Short-term debt outstanding consists of:

	September 30,		December 31,
Short-term Debt	2021		2020
	(In thousands)
PNM:
PNM 2017 New Mexico Credit Facility	$	—	$	10,000
PNMR:
PNMR Revolving Credit Facility	13,900		12,000
PNMR Development Revolving Credit Facility	—		10,000
	$	13,900	$	32,000

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Pension and Other Postretirement Benefit Plans (Tables)

9 Months Ended

Sep. 30, 2021

Retirement Benefits [Abstract]

Schedule of Net Benefit Costs

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

	Three Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	5	$	9	$	—	$	—
Interest cost	4,036		4,985		476		613		90		123
Expected return on plan assets	(7,133)		(7,363)		(1,042)		(1,387)		—		—
Amortization of net loss	4,541		4,465		—		87		99		101
Amortization of prior service cost	—		(138)				—		—		—
Net Periodic Benefit Cost (Income)	$	1,444	$	1,949	$	(561)	$	(678)	$	189	$	224

	Nine Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	18	$	29	$	—	$	—
Interest cost	12,107		14,956		1,430		1,840		271		367
Expected return on plan assets	(21,398)		(22,089)		(3,125)		(4,161)		—		—
Amortization of net loss	13,624		13,395		—		261		296		302
Amortization of prior service cost	—		(415)		—		—		—		—
Net Periodic Benefit Cost (Income)	$	4,333	$	5,847	$	(1,677)	$	(2,031)	$	567	$	669

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

	Three Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	12	$	12	$	—	$	—
Interest cost	435		545		77		93		4		6
Expected return on plan assets	(795)		(821)		(101)		(136)		—		—
Amortization of net (gain) loss	311		315		(81)		(81)		8		6
Amortization of prior service cost	—		—		—		—		—		—
Net Periodic Benefit Cost (Income)	$	(49)	$	39	$	(93)	$	(112)	$	12	$	12

	Nine Months Ended September 30,
	Pension Plan				OPEB Plan				Executive Retirement Program
	2021		2020		2021		2020		2021		2020
	(In thousands)
Components of Net Periodic Benefit Cost
Service cost	$	—	$	—	$	34	$	35	$	—	$	—
Interest cost	1,306		1,633		231		280		13		17
Expected return on plan assets	(2,386)		(2,463)		(304)		(404)		—		—
Amortization of net (gain) loss	935		944		(242)		(243)		25		18
Amortization of prior service cost	—		—		—		—		—		—
Net Periodic Benefit Cost (Income)	$	(145)	$	114	$	(281)	$	(332)	$	38	$	35

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Regulatory and Rate Matters (Tables)

9 Months Ended

Sep. 30, 2021

Regulated Operations [Abstract]

Schedule of Rate Increases for Transmission Costs

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)
October 7, 2020	$	10.8	$	2.0
March 12, 2021	$	112.6	$	14.1
September 20, 2021	$	41.2	$	6.3

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Lease Commitments (Tables)

9 Months Ended

Sep. 30, 2021

Leases [Abstract]

Assets and Liabilities, Lessee

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

	September 30, 2021						December 31, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating leases:
Operating lease assets, net of amortization	$	79,808	$	5,778	$	85,956	$	97,461	$	7,206	$	105,133
Current portion of operating lease liabilities	26,166		1,988		28,230		25,130		2,193		27,460
Long-term portion of operating lease liabilities	51,233		3,579		55,106		75,941		4,779		81,065

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

	September 30, 2021						December 31, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Financing leases:
Non-utility property	$	14,276	$	15,722	$	30,328	$	11,453	$	13,299	$	25,055
Accumulated depreciation	(3,838)		(4,185)		(8,185)		(2,044)		(2,241)		(4,383)
Non-utility property, net	10,438		11,537		22,143		9,409		11,058		20,672
Other current liabilities	2,620		2,897		5,602		1,993		2,397		4,470
Other deferred credits	7,639		8,649		16,373		7,176		8,669		15,972

Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities as of September 30, 2021 is presented below:

	PNM		TNMP		PNMR Consolidated
Weighted average remaining lease term (years):
Operating leases	5.83		3.08		5.65
Financing leases	4.31		4.35		4.32
Weighted average discount rate:
Operating leases	3.99	%	3.97	%	3.98	%
Financing leases	2.62	%	2.72	%	2.67	%

Lease, Cost

Information for the components of lease expense is as follows:

	Three Months Ended September 30, 2021						Nine Months Ended September 30, 2021
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating lease cost:	$	6,569	$	594	$	7,192	$	20,020	$	1,880	$	22,006
Amounts capitalized	(199)		(517)		(716)		(645)		(1,618)		(2,264)
Total operating lease expense	6,370		77		6,476		19,375		262		19,742
Financing lease cost:
Amortization of right-of-use assets	657		693		1,372		1,793		1,944		3,802
Interest on lease liabilities	66		78		145		193		230		426
Amounts capitalized	(452)		(709)		(1,161)		(1,235)		(1,967)		(3,202)
Total financing lease expense	271		62		356		751		207		1,026
Variable lease expense	106		—		106		274		—		274
Short-term lease expense (1)	1,572		2		1,578		1,821		6		1,857
Total lease expense for the period	$	8,319	$	141	$	8,516	$	22,221	$	475	$	22,899

(1) Includes expense of $1.4 million for the three and nine months ended September 30, 2021 for rental of temporary cooling towers associated with the SJGS Unit 1 outage. These amounts are partially offset with insurance reimbursements of $0.9 million for the three and nine months ended September 30, 2021. For additional information on the SJGS Unit 1 outage see Note 12.

	Three Months Ended September 30, 2020						Nine Months Ended September 30, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Operating lease cost:	$	6,798	$	685	$	7,545	$	20,538	$	2,205	$	22,938
Amounts capitalized	(248)		(577)		(825)		(786)		(1,812)		(2,599)
Total operating lease expense	6,550		108		6,720		19,752		393		20,339
Financing lease cost:
Amortization of right-of-use assets	435		439		893		1,022		1,110		2,187
Interest on lease liabilities	58		74		134		156		198		358
Amounts capitalized	(281)		(452)		(733)		(682)		(1,105)		(1,787)
Total financing lease expense	212		61		294		496		203		758
Variable lease expense	63		—		63		158		—		158
Short-term lease expense	16		4		22		176		5		183
Total lease expense for the period	$	6,841	$	173	$	7,099	$	20,582	$	601	$	21,438

Schedule of Leases, Supplemental Cash Flows

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

	Nine Months Ended						Nine Months Ended
	September 30, 2021						September 30, 2020
	PNM		TNMP		PNMR Consolidated		PNM		TNMP		PNMR Consolidated
	(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	25,511	$	262	$	25,897	$	25,804	$	483	$	26,708
Operating cash flows from financing leases	65		24		92		58		32		94
Finance cash flows from financing leases	621		234		920		378		215		646
Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	—	$	317	$	317	$	—	$	—	$	—
Financing leases	2,898		2,642		5,567		5,635		6,309		11,985

Lessee, Operating Lease, Liability, Maturity

Future expected lease payments are shown below:

	As of September 30, 2021
	PNM				TNMP				PNMR Consolidated
	Financing		Operating		Financing		Operating		Financing		Operating
	(In thousands)
Remainder of 2021	$	709	$	334	$	800	$	538	$	1,532	$	935
2022	2,767		26,266		3,125		1,990		5,980		28,467
2023	2,649		17,735		2,906		1,750		5,607		19,665
2024	1,972		7,908		2,438		877		4,421		8,833
2025	1,164		6,946		1,545		702		2,710		7,685
Later years	1,335		27,520		1,417		76		2,752		27,816
Total minimum lease payments	10,596		86,709		12,231		5,933		23,002		93,401
Less: Imputed interest	337		9,310		685		366		1,027		10,065
Lease liabilities as of September 30, 2021	$	10,259	$	77,399	$	11,546	$	5,567	$	21,975	$	83,336

Finance Lease, Liability, Maturity

Future expected lease payments are shown below:

	As of September 30, 2021
	PNM				TNMP				PNMR Consolidated
	Financing		Operating		Financing		Operating		Financing		Operating
	(In thousands)
Remainder of 2021	$	709	$	334	$	800	$	538	$	1,532	$	935
2022	2,767		26,266		3,125		1,990		5,980		28,467
2023	2,649		17,735		2,906		1,750		5,607		19,665
2024	1,972		7,908		2,438		877		4,421		8,833
2025	1,164		6,946		1,545		702		2,710		7,685
Later years	1,335		27,520		1,417		76		2,752		27,816
Total minimum lease payments	10,596		86,709		12,231		5,933		23,002		93,401
Less: Imputed interest	337		9,310		685		366		1,027		10,065
Lease liabilities as of September 30, 2021	$	10,259	$	77,399	$	11,546	$	5,567	$	21,975	$	83,336

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Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2021

Related Party Transactions [Abstract]

Schedule of Related Party Transactions

The table below summarizes the nature and amount of related party transactions of PNMR, PNM, TNMP, and NMRD:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
	(In thousands)
Services billings:
PNMR to PNM	$	23,617	$	24,204	$	75,992	$	70,848
PNMR to TNMP	9,187		9,645		29,687		28,075
PNM to TNMP	107		106		319		295
TNMP to PNMR	—		35		24		106
PNMR to NMRD	55		74		165		199
Renewable energy purchases:
PNM from NMRD	3,384		3,723		9,473		7,646
Interconnection billings:
PNM to NMRD	225		—		225		350
PNM to PNMR	—		—		—		—
NMRD to PNM	—		—		1,276		—
Interest billings:
PNMR to PNM	—		—		—		6
PNM to PNMR	36		60		108		218
PNMR to TNMP	—		—		—		2
Income tax sharing payments:
PNMR to PNM	—		—		—		—
TNMP to PNMR	—		—		—		—

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Equity Method Investment (Tables)

9 Months Ended

Sep. 30, 2021

Equity Method Investments and Joint Ventures [Abstract]

Marketable Securities

Summarized financial information for NMRD is as follows:

	Results of Operations
	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In thousands)
Operating revenues	$	3,543	$	3,462	$	10,179	$	7,769
Operating expenses	2,422		2,100		7,360		5,152
Net earnings	$	1,121	$	1,362	$	2,819	$	2,617

	Financial Position
	September 30,		December 31,
	2021		2020
	(In thousands)
Current assets	$	9,164	$	8,046
Net property, plant, and equipment	168,053		172,585
Non-current assets	2,448		1,900
Total assets	179,665		182,531
Current liabilities	1,166		841
Non-current liabilities	370		380
Owners’ equity	$	178,129	$	181,310

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Significant Accounting Policies and Responsibility for Financial Statements (Details) - USD ($)	1 Months Ended				3 Months Ended		9 Months Ended
	Sep. 30, 2021	Jul. 30, 2021	Sep. 30, 2020	Jul. 31, 2020	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Business Acquisition [Line Items]
Payment defaults under agreements	$ 0				$ 0		$ 0
Dividends declared per common share (dollars per share)	$ 0.3275	$ 0.3275	$ 0.3075	$ 0.3075	$ 0.3275	$ 0.3075	$ 0.9825	$ 0.9225
Dividends declared on common stock					$ 56,222,000	$ 48,987,000	$ 84,333,000	$ 73,480,000
PNMR
Business Acquisition [Line Items]
Equity contribution from parent					0
PNM
Business Acquisition [Line Items]
Dividends declared on common stock					$ 60,000,000	0	60,000,000	40,654,000
Texas-New Mexico Power Company
Business Acquisition [Line Items]
Equity contribution from parent							$ 52,000,000	0
Dividends declared on common stock						$ 16,174,000		$ 34,613,000

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Segment Information - Summarized Financial Information (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($) segment	Sep. 30, 2020 USD ($)	Dec. 31, 2020 USD ($)
Segment Reporting Information [Line Items]
Number of operating segments | segment			1
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	$ 554,551	$ 472,465	$ 1,345,798	$ 1,163,736
Other operating expenses	132,004	122,269	397,209	363,084
Depreciation and amortization	71,438	68,400	212,039	207,395
Operating income	151,729	147,805	269,098	266,693
Interest income	3,329	3,180	10,466	9,674
Other income (deductions)	2,536	14,062	16,864	2,759
Interest charges	(23,244)	(27,263)	(73,247)	(88,785)
Earnings before Income Taxes	134,350	137,784	223,181	190,341
Income taxes (benefit)	16,668	12,331	26,533	14,726
Net Earnings	117,682	125,453	196,648	175,615
Valencia non-controlling interest	(4,229)	(3,553)	(11,643)	(11,222)
Subsidiary preferred stock dividends	(132)	(132)	(396)	(396)
Net Earnings Available for PNM Common Stock	113,321	121,768	184,609	163,997
Total Assets	8,256,070	7,742,112	8,256,070	7,742,112	$ 7,939,854
Goodwill	278,297	278,297	278,297	278,297	$ 278,297
PNM
Segment Reporting Information, Profit (Loss) [Abstract]
Other operating expenses	107,385	99,171	320,638	299,284
Depreciation and amortization	42,673	40,509	127,111	123,721
Operating income	114,563	116,540	199,380	199,728
Interest income	3,364	3,239	10,376	9,882
Other income (deductions)	1,358	11,563	13,705	(1,509)
Interest charges	(12,509)	(14,747)	(38,441)	(51,554)
Earnings before Income Taxes	106,776	116,595	185,020	156,547
Income taxes (benefit)	15,500	13,591	26,178	16,127
Net Earnings	91,276	103,004	158,842	140,420
Valencia non-controlling interest	(4,229)	(3,553)	(11,643)	(11,222)
Subsidiary preferred stock dividends	(132)	(132)	(396)	(396)
Net Earnings Available for PNM Common Stock	86,915	99,319	146,803	128,802
Total Assets	5,723,176	5,449,238	5,723,176	5,449,238
Goodwill	51,632	51,632	51,632	51,632
TNMP
Segment Reporting Information, Profit (Loss) [Abstract]
Other operating expenses	28,677	27,983	82,950	78,444
Depreciation and amortization	23,031	22,492	67,696	66,696
Operating income	38,842	31,779	80,571	69,299
Interest income	0	0	0	0
Other income (deductions)	1,144	2,286	3,251	4,810
Interest charges	(8,403)	(7,942)	(25,155)	(22,475)
Earnings before Income Taxes	31,583	26,123	58,667	51,634
Income taxes (benefit)	3,642	2,202	6,341	4,447
Net Earnings	27,941	23,921	52,326	47,187
Valencia non-controlling interest	0	0	0	0
Subsidiary preferred stock dividends	0	0	0	0
Net Earnings Available for PNM Common Stock	27,941	23,921	52,326	47,187
Total Assets	2,311,559	2,075,291	2,311,559	2,075,291
Goodwill	226,665	226,665	226,665	226,665
Corporate and Other
Segment Reporting Information, Profit (Loss) [Abstract]
Other operating expenses	(4,058)	(4,885)	(6,379)	(14,644)
Depreciation and amortization	5,734	5,399	17,232	16,978
Operating income	(1,676)	(514)	(10,853)	(2,334)
Interest income	(35)	(59)	90	(208)
Other income (deductions)	34	213	(92)	(542)
Interest charges	(2,332)	(4,574)	(9,651)	(14,756)
Earnings before Income Taxes	(4,009)	(4,934)	(20,506)	(17,840)
Income taxes (benefit)	(2,474)	(3,462)	(5,986)	(5,848)
Net Earnings	(1,535)	(1,472)	(14,520)	(11,992)
Valencia non-controlling interest	0	0	0	0
Subsidiary preferred stock dividends	0	0	0	0
Net Earnings Available for PNM Common Stock	(1,535)	(1,472)	(14,520)	(11,992)
Total Assets	221,335	217,583	221,335	217,583
Goodwill	0	0	0	0
Cost of energy
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	554,551	472,465	1,345,798	1,163,736
Cost of energy	199,380	133,991	467,452	326,564
Utility margin	355,171	338,474	878,346	837,172
Cost of energy | PNM
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	435,523	364,504	1,030,685	873,425
Cost of energy	170,902	108,284	383,556	250,692
Utility margin	264,621	256,220	647,129	622,733
Cost of energy | TNMP
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	119,028	107,961	315,113	290,311
Cost of energy	28,478	25,707	83,896	75,872
Utility margin	90,550	82,254	231,217	214,439
Cost of energy | Corporate and Other
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	0	0	0	0
Cost of energy	0	0	0	0
Utility margin	$ 0	$ 0	$ 0	$ 0

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Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	$ 2,145,398	$ 1,756,427	$ 2,108,474	$ 1,741,750
Total Other Comprehensive Income (Loss)	(1,267)	2,705	(1,437)	9,501
Ending balance	2,201,364	1,832,595	2,201,364	1,832,595
Total
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(79,353)	(92,581)	(79,183)	(99,377)
Amounts reclassified from AOCI (pre-tax)			(2,762)	(2,048)
Income tax impact of amounts reclassified			701	521
Other OCI changes (pre-tax)			836	14,783
Income tax impact of other OCI changes			(212)	(3,755)
Total Other Comprehensive Income (Loss)	(1,267)	2,705	(1,437)	9,501
Ending balance	(80,620)	(89,876)	(80,620)	(89,876)
Fair Value Adjustment for Cash Flow Hedges
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance			(672)	(322)
Amounts reclassified from AOCI (pre-tax)			(903)	(1,117)
Income tax impact of amounts reclassified			229	284
Other OCI changes (pre-tax)			1,804	33
Income tax impact of other OCI changes			(458)	(9)
Total Other Comprehensive Income (Loss)			672	(809)
Ending balance	0	(1,131)	0	(1,131)
PNM
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	1,920,956	1,506,198	1,863,752	1,512,431
Total Other Comprehensive Income (Loss)	(1,267)	2,247	(2,109)	10,310
Ending balance	1,945,851	1,607,116	1,945,851	1,607,116
PNM | Total
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(79,353)	(90,992)	(78,511)	(99,055)
Amounts reclassified from AOCI (pre-tax)			(1,859)	(931)
Income tax impact of amounts reclassified			472	237
Other OCI changes (pre-tax)			(968)	14,750
Income tax impact of other OCI changes			246	(3,746)
Total Other Comprehensive Income (Loss)	(1,267)	2,247	(2,109)	10,310
Ending balance	(80,620)	(88,745)	(80,620)	(88,745)
PNM | Unrealized Gains on Available-for-Sale Securities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance			20,403	10,638
Amounts reclassified from AOCI (pre-tax)			(8,120)	(7,156)
Income tax impact of amounts reclassified			2,062	1,818
Other OCI changes (pre-tax)			(968)	14,750
Income tax impact of other OCI changes			246	(3,746)
Total Other Comprehensive Income (Loss)			(6,780)	5,666
Ending balance	13,623	16,304	13,623	16,304
PNM | Pension Liability Adjustment
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance			(98,914)	(109,693)
Amounts reclassified from AOCI (pre-tax)			6,261	6,225
Income tax impact of amounts reclassified			(1,590)	(1,581)
Other OCI changes (pre-tax)			0	0
Income tax impact of other OCI changes			0	0
Total Other Comprehensive Income (Loss)			4,671	4,644
Ending balance	$ (94,243)	$ (105,049)	$ (94,243)	$ (105,049)

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Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Earnings Per Share [Abstract]
Net Earnings Attributable to PNMR	$ 113,321	$ 121,768	$ 184,609	$ 163,997
Average Number of Common Shares:
Outstanding during period (in shares)	85,835	79,654	85,835	79,654
Vested awards of restricted stock (in shares)	237	213	230	205
Average Shares – Basic (in shares)	86,072	79,867	86,065	79,859
Dilutive Effect of Common Stock Equivalents:
PNMR 2020 Forward Equity Sale Agreements (in shares)	0	0	0	57
Restricted stock (in shares)	41	39	41	38
Average Shares – Diluted (in shares)	86,113	79,906	86,106	79,954
Net Earnings Per Share of Common Stock:
Basic (in dollars per share)	$ 1.32	$ 1.52	$ 2.14	$ 2.05
Diluted (in dollars per share)	$ 1.32	$ 1.52	$ 2.14	$ 2.05

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Electric Operating Revenues - Narrative (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2021 USD ($) utility	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($) utility	Sep. 30, 2020 USD ($)	Dec. 31, 2020 USD ($)
Disaggregation of Revenue [Line Items]
Number of regulated utilities | utility	2		2
Accounts receivable, allowance for credit loss, period increase	$ 500,000	$ 2,000,000	$ 2,900,000	$ 2,700,000
Other receivables, allowance for credit loss, period increase	800,000		800,000
Contract assets	0		0		$ 0
PNM
Disaggregation of Revenue [Line Items]
Accounts receivable	98,600,000		98,600,000		$ 86,200,000
Texas-New Mexico Power Company
Disaggregation of Revenue [Line Items]
Regulatory assets	$ 800,000		$ 800,000

XML

Electric Operating Revenues - Disaggregation of revenues (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 481,881	$ 455,120	$ 1,197,359	$ 1,121,177
Alternative revenue programs	(9,483)	(12,376)	(3,156)	(7,484)
Other electric operating revenue	82,153	29,721	151,595	50,043
Revenues	554,551	472,465	1,345,798	1,163,736
PNM
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	361,701	341,850	884,559	825,759
Alternative revenue programs	(8,331)	(7,067)	(5,469)	(2,377)
Other electric operating revenue	82,153	29,721	151,595	50,043
Revenues	435,523	364,504	1,030,685	873,425
TNMP
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	120,180	113,270	312,800	295,418
Alternative revenue programs	(1,152)	(5,309)	2,313	(5,107)
Other electric operating revenue	0	0	0	0
Revenues	119,028	107,961	315,113	290,311
Cost of energy
Disaggregation of Revenue [Line Items]
Revenues	554,551	472,465	1,345,798	1,163,736
Cost of energy | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	206,874	211,663	499,394	492,763
Cost of energy | Commercial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	171,505	156,491	420,422	392,995
Cost of energy | Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	32,138	32,317	88,214	85,545
Cost of energy | Public authority
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	9,002	9,450	21,873	21,547
Cost of energy | Economy energy service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	7,389	3,270	24,722	11,802
Cost of energy | PNM | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	155,035	158,549	377,794	370,448
Cost of energy | PNM | Commercial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	137,071	125,414	327,090	305,127
Cost of energy | PNM | Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	24,856	25,475	66,593	65,313
Cost of energy | PNM | Public authority
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	7,388	7,982	17,312	17,236
Cost of energy | PNM | Economy energy service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	7,389	3,270	24,722	11,802
Cost of energy | TNMP | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	51,839	53,114	121,600	122,315
Cost of energy | TNMP | Commercial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	34,434	31,077	93,332	87,868
Cost of energy | TNMP | Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	7,282	6,842	21,621	20,232
Cost of energy | TNMP | Public authority
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,614	1,468	4,561	4,311
Cost of energy | TNMP | Economy energy service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Transmission
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	50,534	37,308	129,768	103,822
Transmission | PNM
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	26,459	17,463	60,919	45,727
Transmission | TNMP
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	24,075	19,845	68,849	58,095
Miscellaneous
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4,439	4,621	12,966	12,703
Miscellaneous | PNM
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	3,503	3,697	10,129	10,106
Miscellaneous | TNMP
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 936	$ 924	$ 2,837	$ 2,597

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Variable Interest Entities (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021 USD ($) MW	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($) MW	Sep. 30, 2020 USD ($)	Dec. 31, 2020 USD ($)	Jan. 31, 2016 USD ($)
Results of Operations
Operating revenues	$ 554,551	$ 472,465	$ 1,345,798	$ 1,163,736
Operating expenses	402,822	324,660	1,076,700	897,043
Earnings attributable to non-controlling interest	4,229	3,553	11,643	11,222
Financial Position
Current assets	447,713		447,713		$ 377,479
Assets	8,256,070	7,742,112	8,256,070	7,742,112	7,939,854
Current liabilities	475,207		475,207		977,662
Owners’ equity – non-controlling interest	56,414		56,414		59,009
PNM
Results of Operations
Operating revenues	435,523	364,504	1,030,685	873,425
Operating expenses	320,960	247,964	831,305	673,697
Earnings attributable to non-controlling interest	4,229	3,553	11,643	11,222
Financial Position
Current assets	377,284		377,284		322,128
Assets	5,723,176		5,723,176		5,581,033
Current liabilities	357,122		357,122		594,332
Owners’ equity – non-controlling interest	56,414		56,414		59,009
PNM | Valencia
Variable Interest Entity [Line Items]
Payment for fixed costs	5,000	5,000	14,900	15,000
Payment for variable costs	700	300	$ 1,600	1,200
Long-term contract option to purchase, ownership percentage (up to)			50.00%
Long-term contract option to purchase, purchase price - percentage of adjusted NBV			50.00%
Long-term contract option to purchase, purchase price - percentage of FMV			50.00%
Results of Operations
Operating revenues	5,719	5,278	$ 16,425	16,126
Operating expenses	1,490	1,725	4,782	4,904
Earnings attributable to non-controlling interest	4,229	$ 3,553	11,643	$ 11,222
Financial Position
Current assets	3,981		3,981		3,911
Net property, plant, and equipment	53,617		53,617		55,744
Assets	57,598		57,598		59,655
Current liabilities	1,184		1,184		646
Owners’ equity – non-controlling interest	$ 56,414		$ 56,414		$ 59,009
PNM | Purchased through May 2028 | Valencia
Variable Interest Entity [Line Items]
Number of megawatts purchased (in megawatts) | MW	155		155
NM Capital | San Juan Generating Station | Coal supply
Variable Interest Entity [Line Items]
Cash used to support bank letter or credit arrangement	$ 30,300		$ 30,300			$ 30,300

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Fair Value of Derivative and Other Financial Instruments - Narrative (Details)	3 Months Ended			9 Months Ended		12 Months Ended
	Sep. 30, 2021 USD ($) MW power_purchase_agreement gal	Mar. 31, 2021 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($) MWh MW	Sep. 30, 2020 USD ($)	Dec. 31, 2020 USD ($) MWh gal
Debt Securities, Available-for-sale [Line Items]
Number of purchase power agreements | power_purchase_agreement	3
Obligations to return cash	$ 900,000			$ 900,000		$ 900,000
Contract in a liability position	0			0		0
Debt securities, available-for-sale, unrealized loss position	$ 0			0		0
Other than temporary impairments				$ 0		0
PNM
Debt Securities, Available-for-sale [Line Items]
Number of purchase power agreements | power_purchase_agreement	3
Expected exposure to market risk (in megawatts) | MW	65			65
Power to be sold to third party (in megawatts) | MW	36			36
Amounts recognized for right to reclaim cash	$ 0			$ 0		0
Cash collateral under margin arrangements	500,000			500,000		$ 500,000
(Increase)/decrease in other than temporary losses of available-for-sale securities, net portion recognized in earnings	$ 600,000		$ 4,200,000	$ 1,200,000	$ (4,500,000)
PNM | Natural Gas Cost | Unusual Weather
Debt Securities, Available-for-sale [Line Items]
Cost of energy		$ 20,000,000
PNM | Electricity, Purchased | Unusual Weather
Debt Securities, Available-for-sale [Line Items]
Cost of energy		$ 8,000,000
PNM | Commodity derivatives | Fair value hedging
Debt Securities, Available-for-sale [Line Items]
Economic Hedges (in mmbtu and mwh) | MWh				111,512		0
Open gas commodity volume positions | gal	0					0
PNM | Commodity derivatives | Designated as Hedging Instrument
Debt Securities, Available-for-sale [Line Items]
Derivative asset, gross liability	$ 700,000			$ 700,000
Derivative asset, gross asset	700,000			700,000
Other current assets	753,000			753,000		$ 1,096,000
Current derivative liability	2,703,000			2,703,000		1,096,000
PNM | Commodity derivatives | Designated as Hedging Instrument | Cost of energy
Debt Securities, Available-for-sale [Line Items]
Total gain	100,000		$ 100,000	100,000	$ 100,000
PNM | Fuel and purchased power costs | Commodity derivatives | Designated as Hedging Instrument
Debt Securities, Available-for-sale [Line Items]
Other current assets	100,000			100,000		0
Current derivative liability	$ 2,000,000			$ 2,000,000		0
PNM | Portfolio One
Debt Securities, Available-for-sale [Line Items]
Number of megawatts available in purchase power agreement | MW	85			85
PNM | Portfolio Three
Debt Securities, Available-for-sale [Line Items]
Number of megawatts available in purchase power agreement | MW	40			40
PNM | Portfolio Two
Debt Securities, Available-for-sale [Line Items]
Number of megawatts available in purchase power agreement | MW	150			150
PNM | Tri-State
Debt Securities, Available-for-sale [Line Items]
Power to be sold to third party (in megawatts) | MW	100			100
PNM | Recurring
Debt Securities, Available-for-sale [Line Items]
Available-for-sale debt securities	$ 455,409,000			$ 455,409,000		440,115,000
Nuclear Decommissioning Trust | PNM | Recurring
Debt Securities, Available-for-sale [Line Items]
Available-for-sale debt securities	392,200,000			392,200,000		379,200,000
Mine Reclamation Trust | PNM | Recurring
Debt Securities, Available-for-sale [Line Items]
Available-for-sale debt securities	$ 63,200,000			$ 63,200,000		$ 60,900,000

XML

Fair Value of Derivative and Other Financial Instruments - Overview and Commodity Derivatives (Details) - PNM - Designated as Hedging Instrument - Commodity derivatives - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Derivatives, Fair Value [Line Items]
Other current assets	$ 753	$ 1,096
Other deferred charges	0	455
Derivative asset	753	1,551
Other current liabilities	(2,703)	(1,096)
Other deferred credits	0	(455)
Derivative liability	(2,703)	(1,551)
Net	$ (1,950)	$ 0

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Fair Value of Derivative and Other Financial Instruments - Investments in NDT and Gross Realized Losses (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Equity securities:
Net gains (losses) from equity securities sold	$ (309)	$ 90	$ 5,931	$ 4,131
Net gains (losses) from equity securities still held	(3,153)	8,545	2,388	2,991
Total net gains (losses) on equity securities	(3,462)	8,635	8,319	7,122
Available-for-sale debt securities:
Net gains (losses) on debt securities	5,410	5,766	7,789	(3,950)
Net gains on investment securities	1,948	14,401	16,108	3,172
PNM
Available-for-sale debt securities:
Proceeds from sales	128,683	134,567	396,870	489,218
Gross realized gains	10,986	12,998	30,290	30,085
Gross realized (losses)	$ (6,527)	$ (11,374)	$ (17,776)	$ (25,411)

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Fair Value of Derivative and Other Financial Instruments - Maturities of Debt Securities (Details) - PNMR and PNM $ in Thousands	Sep. 30, 2021 USD ($)
Available-for-Sale
Within 1 year	$ 26,085
After 1 year through 5 years	77,703
After 5 years through 10 years	93,532
After 10 years through 15 years	21,475
After 15 years through 20 years	13,858
After 20 years	33,306
Available-for-sale debt securities	$ 265,959

XML

Fair Value of Derivative and Other Financial Instruments - Items Recorded and Presented by Level of Hierarchy (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
PNMR	$ 3,724,723	$ 3,355,761
Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
PNMR	3,500,233	3,295,150
PNM
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
PNMR	1,834,677	1,602,547
PNM | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
PNMR	1,732,442	1,696,620
TNMP
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
PNMR	1,040,046	1,006,722
TNMP | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
PNMR	918,074	853,673
Recurring | PNM
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	455,409	440,115
Investments, unrealized gain	18,299	27,387
Recurring | PNM | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	198,484	183,330
Recurring | PNM | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	256,925	256,785
Recurring | PNM | Cash and cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	8,229	6,107
Recurring | PNM | Cash and cash equivalents | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	8,229	6,107
Recurring | PNM | Cash and cash equivalents | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	0	0
Recurring | PNM | Corporate stocks, common
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	99,681	85,271
Recurring | PNM | Corporate stocks, common | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	99,681	85,271
Recurring | PNM | Corporate stocks, common | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	0	0
Recurring | PNM | Corporate stocks, preferred
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	9,046	9,910
Recurring | PNM | Corporate stocks, preferred | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	3,256	3,608
Recurring | PNM | Corporate stocks, preferred | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	5,790	6,302
Recurring | PNM | Mutual funds and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	72,494	58,817
Recurring | PNM | Mutual funds and other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	72,404	58,762
Recurring | PNM | Mutual funds and other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	90	55
Recurring | PNM | U.S. government
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	44,408	55,839
Investments, unrealized gain	270	950
Recurring | PNM | U.S. government | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	14,914	29,579
Recurring | PNM | U.S. government | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	29,494	26,260
Recurring | PNM | International government
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	16,925	16,032
Investments, unrealized gain	1,782	2,537
Recurring | PNM | International government | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	0	0
Recurring | PNM | International government | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	16,925	16,032
Recurring | PNM | Municipals
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	47,860	50,139
Investments, unrealized gain	1,896	2,779
Recurring | PNM | Municipals | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	0	0
Recurring | PNM | Municipals | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	47,860	50,139
Recurring | PNM | Corporate and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	156,766	158,000
Investments, unrealized gain	14,351	21,121
Recurring | PNM | Corporate and other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	0	3
Recurring | PNM | Corporate and other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	$ 156,766	$ 157,997

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Stock-Based Compensation - Narrative (Details) - USD ($) $ in Millions	9 Months Ended	123 Months Ended
	Sep. 30, 2021	Mar. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)		0
Restricted Shares and Performance Based Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized expense related to stock awards	$ 5.2
Period of time stock expense is expected to be recognized	1 year 8 months 12 days
Executive | Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum number of shares awarded in year one (in shares)	142,080
Maximum number of shares awarded in year two (in shares)	142,047
Maximum number of shares awarded in year three (in shares)	152,414
Performance period	3 years
Executive | Performance Shares | Achieved performance target for 2017 through 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum number of shares awarded in year one (in shares)	124,941
Performance Equity Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period	3 years
Vesting rate	100.00%
Performance Equity Plan | Non-employee Members of the Board of Directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period	1 year

XML

Stock-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Thousands	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Total intrinsic value of options exercised	$ 0	$ 84
Restricted Shares and Performance Based Shares
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Expected quarterly dividends per share (in dollars per share)	$ 0.3275	$ 0.3075
Risk-free interest rate	0.32%	0.72%
Restricted Stock
Restricted Stock, Shares
Outstanding at beginning of period (in shares)	168,061
Granted (in shares)	213,515
Exercised (in shares)	(210,572)
Forfeited (in shares)	(1,741)
Outstanding at end of period (in shares)	169,263
Restricted Stock, Weighted- Average Grant Date Fair Value
Outstanding at beginning of period (in dollars per share)	$ 40.77
Granted (in dollars per share)	43.48	$ 36.73
Exercised (in dollars per share)	40.73
Forfeited (in dollars per share)	43.72
Outstanding at end of period (in dollars per share)	43.71
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Weighted-average grant date fair value (in dollars per share)	$ 43.48	$ 36.73
Total fair value of restricted shares that vested	$ 10,018	$ 11,740
Market-Based Shares
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Risk-free interest rate	0.29%	0.72%
Dividend yield	2.76%	2.51%
Expected volatility	33.69%	19.41%

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Financing - Financing Activities (Details)										9 Months Ended
	Jul. 14, 2021 USD ($) bond_series	Jun. 18, 2021 USD ($)	May 18, 2021 USD ($)	Mar. 09, 2021 USD ($)	Dec. 22, 2020 USD ($)	Jun. 22, 2020 USD ($)	Apr. 30, 2020 USD ($)	Apr. 15, 2020 USD ($)	Jan. 01, 2020	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Oct. 22, 2021 USD ($)	Oct. 01, 2021	Sep. 23, 2021 USD ($) bond_series	Aug. 16, 2021 USD ($) bond_series	Dec. 31, 2020 USD ($)	Dec. 21, 2020 USD ($)	Aug. 31, 2020 USD ($)	Jul. 15, 2020 USD ($)	Jun. 30, 2020 USD ($)	Jun. 01, 2020 USD ($)	Apr. 24, 2020 USD ($) bond_series	Dec. 31, 2019 USD ($) bond_series	Mar. 09, 2018 USD ($)
Debt Instrument [Line Items]
Financing capacity										$ 40,000,000
Repayments of Long-term Debt										1,165,000,000	$ 752,845,000
Subsequent event
Debt Instrument [Line Items]
Remaining borrowing capacity												$ 798,800,000
PNMR 2020 Delayed-Draw Term Loan
Debt Instrument [Line Items]
Aggregate principal amount					$ 300,000,000
Proceeds from issuance of debt					$ 80,000,000
Remaining borrowing capacity				$ 220,000,000
PNM
Debt Instrument [Line Items]
Repayments of Long-term Debt										$ 200,000,000	$ 752,845,000
PNM | Subsequent event
Debt Instrument [Line Items]
Remaining borrowing capacity												397,800,000
PNM | PNM 2019 40 Million Term Loan
Debt Instrument [Line Items]
Repayments of debt		$ 40,000,000
PNM | Maximum
Debt Instrument [Line Items]
Maturity term over which financings require regulator approval (more than)										18 months
Texas-New Mexico Power Company | Subsequent event
Debt Instrument [Line Items]
Remaining borrowing capacity												$ 75,000,000
Line of credit
Debt Instrument [Line Items]
Ratio of debt to capital (less than or equal to)										70.00%
Line of credit | PNMR 2021 Delayed-Draw Term Loan | Revolving credit facility
Debt Instrument [Line Items]
Financing capacity			$ 1,000,000,000
Line of credit | PNMR 2020 Delayed-Draw Term Loan | Revolving credit facility
Debt Instrument [Line Items]
Proceeds from long-term lines of credit			850,000,000
Line of credit facility, interest rate at period end										0.94%
Line of credit | PNMR Revolving Credit Facility | Revolving credit facility
Debt Instrument [Line Items]
Repayments of debt			92,100,000
Line of credit | PNMR Development Revolving Credit Facility | Revolving credit facility
Debt Instrument [Line Items]
Repayments of debt			40,000,000
Line of credit | PNM and TNMP
Debt Instrument [Line Items]
Ratio of debt to capital (less than or equal to)										65.00%
Line of credit | PNM | PNM Revolving Credit Facility
Debt Instrument [Line Items]
Repayments of debt							$ 100,000,000
Bonds
Debt Instrument [Line Items]
Repayments of debt						$ 302,500,000
Bonds | City of Farmington, New Mexico
Debt Instrument [Line Items]
Aggregate principal amount																					$ 266,500,000
Bonds | Pollution Control Revenue Bonds, Due 2033
Debt Instrument [Line Items]
Term loans																$ 146,000,000
Stated interest rate																2.15%
Bonds | PNMR 2021 Delayed-Draw Term Loan
Debt Instrument [Line Items]
Variable interest rate										0.94%
Bonds | PNMR 2020 Delayed-Draw Term Loan
Debt Instrument [Line Items]
Repayments of debt			300,000,000
Bonds | PNMR 2019 Term Loan
Debt Instrument [Line Items]
Repayments of debt			150,000,000
Bonds | PNMR 2020 Term Loan
Debt Instrument [Line Items]
Repayments of debt			150,000,000
Bonds | Pollution Control Revenue Bonds
Debt Instrument [Line Items]
Term loans																							$ 100,300,000
Stated interest rate										0.11%
Variable interest rate										0.11%
Bonds | Pollution Control Revenue Bonds, Due 2040
Debt Instrument [Line Items]
Term loans																							$ 40,000,000
Debt instrument, series of bond issuance | bond_series																							2
Bonds | Pollution Control Revenue Bonds, Due 2043, Series 1
Debt Instrument [Line Items]
Term loans																							$ 39,300,000
Bonds | Pollution Control Revenue Bonds, Due 2043, Series 2
Debt Instrument [Line Items]
Term loans																							$ 21,000,000
Bonds | PNM 2021 Fixed Rate PCRBs | Subsequent event
Debt Instrument [Line Items]
Stated interest rate													0.875%
Bonds | Pollution Control Revenue Bonds at 6.25% | Maricopa County, Arizona Pollution Control Corporation
Debt Instrument [Line Items]
Stated interest rate																				6.25%			6.25%
Aggregate principal amount																				$ 36,000,000			$ 36,000,000
Debt instrument, redemption price, percentage									101.00%
Bonds | Pollution Control Revenue Bonds at 6.25% | City of Farmington, New Mexico
Debt Instrument [Line Items]
Stated interest rate																				6.25%			6.25%
Aggregate principal amount																				$ 11,500,000			$ 11,500,000
Bonds | Pollution Control Revenue Bonds at 5.90% | City of Farmington, New Mexico
Debt Instrument [Line Items]
Stated interest rate																				5.90%			5.90%
Aggregate principal amount																				$ 255,000,000			$ 255,000,000
Bonds | PNM | PNM 2021 75 Million Term Loan
Debt Instrument [Line Items]
Variable interest rate										0.91%
Mortgage Bonds | Texas-New Mexico Power Company | TNMP 2021 Bond Purchase Agreement
Debt Instrument [Line Items]
Stated interest rate															2.44%
Aggregate principal amount															$ 65,000,000
Debt instrument, series of bond issuance | bond_series															1
Mortgage Bonds | Texas-New Mexico Power Company | TNMP 2020 Bond Purchase Agreement
Debt Instrument [Line Items]
Aggregate principal amount																						$ 185,000,000
Debt instrument, series of bond issuance | bond_series																						4
Mortgage Bonds | Texas-New Mexico Power Company | TNMP 2020 Bond Purchase Agreement, Bond Series 1 and 2
Debt Instrument [Line Items]
Aggregate principal amount																						$ 110,000,000
Mortgage Bonds | Texas-New Mexico Power Company | TNMP 2020 Bond Purchase Agreement, Bond Series 3 and 4
Debt Instrument [Line Items]
Aggregate principal amount																			$ 75,000,000
Mortgage Bonds | Texas-New Mexico Power Company | TNMP First Mortgage Bonds
Debt Instrument [Line Items]
Aggregate principal amount										$ 750,000,000
Debt instrument, prepayment period										30 days
Debt instrument, redemption price, percentage of principal amount redeemed										100.00%
Senior Notes | PNM 2021 SUNs at 2.59% due July 15, 2033
Debt Instrument [Line Items]
Stated interest rate	2.59%
Aggregate principal amount	$ 80,000,000
Senior Notes | PNM 2021 SUNs at 3.14% due July 15, 2041
Debt Instrument [Line Items]
Stated interest rate	3.14%
Aggregate principal amount	$ 80,000,000
Senior Notes | PNM SUNs at 5.35% due October 1, 2021
Debt Instrument [Line Items]
Stated interest rate	5.35%
Repayments of debt	$ 160,000,000
Senior Notes | Senior Unsecured Notes, 3.21% Series A, due April 2030
Debt Instrument [Line Items]
Stated interest rate							3.21%
Aggregate principal amount							$ 150,000,000
Senior Notes | Senior Unsecured Notes, 3.57% Series B, due April 2039
Debt Instrument [Line Items]
Stated interest rate							3.57%
Aggregate principal amount							$ 50,000,000
Senior Notes | Two Point Two Nine Percent Senior Unsecured Notes Due July 15, 2033
Debt Instrument [Line Items]
Stated interest rate														2.29%
Aggregate principal amount														$ 50,000,000
Senior Notes | Two Point Nine Seven Senior Unsecured Notes Due July 15, 2041
Debt Instrument [Line Items]
Stated interest rate														2.97%
Aggregate principal amount														$ 100,000,000
Senior Notes | PNM
Debt Instrument [Line Items]
Aggregate principal amount							200,000,000
Senior Notes | PNM | PNM 2021 Note Purchase Agreement
Debt Instrument [Line Items]
Aggregate principal amount	$ 160,000,000
Debt instrument, series of bond issuance | bond_series	2
Senior Notes | PNM | PNM 2020 250 Million Term Loan
Debt Instrument [Line Items]
Repayments of debt							100,000,000
Proceeds from issuance of debt							$ 100,000,000
Senior Notes | PNM | PNM September 2021 Note Purchase Agreement
Debt Instrument [Line Items]
Aggregate principal amount														$ 150,000,000
Debt instrument, series of bond issuance | bond_series														2
Term loan agreement with banks | PNM | PNM 2021 75 Million Term Loan
Debt Instrument [Line Items]
Aggregate principal amount		$ 75,000,000
Variable interest rate										0.91%
Medium-term Notes | PNMR Development Term Loan
Debt Instrument [Line Items]
Repayments of debt			$ 65,000,000
Medium-term Notes | PNM | PNM 2020 250 Million Term Loan
Debt Instrument [Line Items]
Aggregate principal amount								$ 250,000,000									$ 150,000,000
Medium-term Notes | PNM | PNM 2019 Term Loan
Debt Instrument [Line Items]
Repayments of debt								$ 250,000,000
Letter of credit | WFB LOC Facility
Debt Instrument [Line Items]
Aggregate principal amount																		$ 30,300,000
Unsecured Debt | PNMR 2018 SUNS 3.25% due March 2021
Debt Instrument [Line Items]
Stated interest rate																								3.25%
Aggregate principal amount																								$ 300,000,000
Repayments of debt				$ 80,000,000

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Financing - Short-term Debt and Liquidity (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2021 USD ($) extension_option	Dec. 31, 2017 USD ($) derivative	Oct. 22, 2021 USD ($)	Mar. 23, 2021	Dec. 31, 2020 USD ($)
Short-term Debt [Line Items]
Financing capacity	$ 40,000,000
Short-term debt	13,900,000				$ 32,000,000
Letters of credit outstanding	3,400,000
Notes payable, related parties	0				0
Variable Rate Short-Term Debt
Short-term Debt [Line Items]
Term of derivatives		4 years
Aggregate principal amount		$ 50,000,000
PNMR Revolving Credit Facility
Short-term Debt [Line Items]
Short-term debt	$ 13,900,000				12,000,000
PNMR Revolving Credit Facility | PNMR
Short-term Debt [Line Items]
Line of credit facility, interest rate at period end	1.58%
PNMR Development Revolving Credit Facility
Short-term Debt [Line Items]
Short-term debt	$ 0				10,000,000
PNM
Short-term Debt [Line Items]
Short-term debt	0				10,000,000
Letters of credit outstanding	2,200,000
Notes payable, related parties	0				0
PNM | Lines of credit
Short-term Debt [Line Items]
NMPRC approved credit facility	40,000,000
PNM | Senior Unsecured Notes PCRB, Reprice Date of June 2022 | Senior Unsecured Notes, Pollution Control Revenue Bonds
Short-term Debt [Line Items]
Unsecured long-term debt, noncurrent	104,500,000
PNM | PNM 2017 New Mexico Credit Facility
Short-term Debt [Line Items]
Short-term debt	0				10,000,000
Letters of credit outstanding	0
PNM | PNM Revolving Credit Facility
Short-term Debt [Line Items]
Letters of credit outstanding	0
TNMP
Short-term Debt [Line Items]
Letters of credit outstanding	0
Notes payable, related parties	0				0
PNMR Development
Short-term Debt [Line Items]
Notes payable, related parties	100,000				$ 300,000
Revolving credit facility
Short-term Debt [Line Items]
Financing capacity	300,000,000
Revolving credit facility | PNM
Short-term Debt [Line Items]
Financing capacity	400,000,000
Revolving credit facility | TNMP
Short-term Debt [Line Items]
Financing capacity	75,000,000
Revolving credit facility | TNMP | First mortgage bonds
Short-term Debt [Line Items]
Collateral amount	$ 75,000,000
Number of extension options | extension_option	2
Extension option period	1 year
Interest rate contract
Short-term Debt [Line Items]
Number of derivatives | derivative		3
Interest rate 1 | Variable Rate Short-Term Debt
Short-term Debt [Line Items]
Fixed interest rate		1.926%		1.926%
Interest rate 2 | Variable Rate Short-Term Debt
Short-term Debt [Line Items]
Fixed interest rate		1.823%
Interest rate 3 | Variable Rate Short-Term Debt
Short-term Debt [Line Items]
Fixed interest rate		1.629%
Subsequent event
Short-term Debt [Line Items]
Notes payable, related parties			$ 0
Remaining borrowing capacity			798,800,000
Subsequent event | PNMR
Short-term Debt [Line Items]
Remaining borrowing capacity			286,000,000
Consolidated invested cash			900,000
Subsequent event | PNM
Short-term Debt [Line Items]
Notes payable, related parties			0
Remaining borrowing capacity			397,800,000
Consolidated invested cash			61,800,000
Subsequent event | PNM | Lines of credit
Short-term Debt [Line Items]
Remaining borrowing capacity			40,000,000
Subsequent event | TNMP
Short-term Debt [Line Items]
Notes payable, related parties			0
Remaining borrowing capacity			75,000,000
Consolidated invested cash			11,400,000
Subsequent event | PNMR Development
Short-term Debt [Line Items]
Notes payable, related parties			$ 200,000

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Pension and Other Postretirement Benefit Plans (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
PNM | Pension Plan
Components of Net Periodic Benefit Cost
Service cost	$ 0	$ 0	$ 0	$ 0
Interest cost	4,036,000	4,985,000	12,107,000	14,956,000
Expected return on plan assets	(7,133,000)	(7,363,000)	(21,398,000)	(22,089,000)
Amortization of net loss	4,541,000	4,465,000	13,624,000	13,395,000
Amortization of prior service cost	0	(138,000)	0	(415,000)
Net Periodic Benefit Cost (Income)	1,444,000	1,949,000	4,333,000	5,847,000
Contributions by employer			0	0
Expected employer contributions, remainder of fiscal year	0		$ 0
PNM | Pension Plan | Maximum
Components of Net Periodic Benefit Cost
Assumptions used calculating net periodic benefit cost, discount rate			2.90%
PNM | OPEB Plan
Components of Net Periodic Benefit Cost
Service cost	5,000	9,000	$ 18,000	29,000
Interest cost	476,000	613,000	1,430,000	1,840,000
Expected return on plan assets	(1,042,000)	(1,387,000)	(3,125,000)	(4,161,000)
Amortization of net loss	0	87,000	0	261,000
Amortization of prior service cost		0	0	0
Net Periodic Benefit Cost (Income)	(561,000)	(678,000)	(1,677,000)	(2,031,000)
Contributions by employer			0	0
Disbursements by employer	1,000,000	1,000,000	2,700,000	3,100,000
Disbursements by employer, remainder of year	3,400,000		3,400,000
Disbursements by employer, after current year	15,100,000		15,100,000
PNM | Executive Retirement Program
Components of Net Periodic Benefit Cost
Service cost	0	0	0	0
Interest cost	90,000	123,000	271,000	367,000
Expected return on plan assets	0	0	0	0
Amortization of net loss	99,000	101,000	296,000	302,000
Amortization of prior service cost	0	0	0	0
Net Periodic Benefit Cost (Income)	189,000	224,000	567,000	669,000
Disbursements by employer	300,000	300,000	1,100,000	1,100,000
Disbursements by employer, remainder of year	1,300,000		1,300,000
Disbursements by employer, after current year	6,000,000		6,000,000
TNMP | Pension Plan
Components of Net Periodic Benefit Cost
Service cost	0	0	0	0
Interest cost	435,000	545,000	1,306,000	1,633,000
Expected return on plan assets	(795,000)	(821,000)	(2,386,000)	(2,463,000)
Amortization of net loss	311,000	315,000	935,000	944,000
Amortization of prior service cost	0	0	0	0
Net Periodic Benefit Cost (Income)	(49,000)	39,000	(145,000)	114,000
Contributions by employer			0	0
Estimated employer contributions for remainder of fiscal year through year 5	0		$ 0
TNMP | Pension Plan | Maximum
Components of Net Periodic Benefit Cost
Assumptions used calculating net periodic benefit cost, discount rate			2.90%
TNMP | OPEB Plan
Components of Net Periodic Benefit Cost
Service cost	12,000	12,000	$ 34,000	35,000
Interest cost	77,000	93,000	231,000	280,000
Expected return on plan assets	(101,000)	(136,000)	(304,000)	(404,000)
Amortization of net loss	(81,000)	(81,000)	(242,000)	(243,000)
Amortization of prior service cost	0	0	0	0
Net Periodic Benefit Cost (Income)	(93,000)	(112,000)	(281,000)	(332,000)
Contributions by employer	0	0	0	0
Estimated employer contributions for remainder of fiscal year through year 5	0		0
TNMP | Executive Retirement Program
Components of Net Periodic Benefit Cost
Service cost	0	0	0	0
Interest cost	4,000	6,000	13,000	17,000
Expected return on plan assets	0	0	0	0
Amortization of net loss	8,000	6,000	25,000	18,000
Amortization of prior service cost	0	0	0	0
Net Periodic Benefit Cost (Income)	12,000	12,000	38,000	35,000
Disbursements by employer, remainder of year	100,000		100,000
Disbursements by employer, after current year	400,000		400,000
TNMP | Executive Retirement Program | Maximum
Components of Net Periodic Benefit Cost
Disbursements by employer	$ 0	$ 0	$ 0	$ 0

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Commitments and Contingencies - Nuclear Spent Fuel and Waste Disposal (Details) - PNM - Nuclear spent fuel and waste disposal - Palo Verde Nuclear Generating Station - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Public Utilities, Commitments And Contingencies [Line Items]
Estimate of possible loss	$ 59.6
Other deferred credits
Public Utilities, Commitments And Contingencies [Line Items]
Loss contingency accrual	$ 13.0	$ 12.8

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Commitments and Contingencies - The Energy Transition Act (Details) - Electric-Generation Portfolio Standard - Energy Transition Act	Jun. 14, 2019
Required Percentage by 2025
Public Utilities, Commitments And Contingencies [Line Items]
Renewable energy, percentage	0.40
Required Percentage by 2030
Public Utilities, Commitments And Contingencies [Line Items]
Renewable energy, percentage	0.50
Required Percentage by 2040
Public Utilities, Commitments And Contingencies [Line Items]
Renewable energy, percentage	0.80
Required Percentage by 2045
Public Utilities, Commitments And Contingencies [Line Items]
Renewable energy, percentage	1

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Commitments and Contingencies - The Clean Air Act (Details)	9 Months Ended
	Sep. 30, 2021 petition option T	Feb. 25, 2019 parts_per_billion	Dec. 31, 2015 parts_per_billion	Oct. 01, 2015 parts_per_billion	Dec. 31, 1999 state
Public Utilities, Commitments And Contingencies [Line Items]
Number of petitions for writ of certiorari | petition	4
Number of options for meeting BTA standards | option	7
Clean Air Act related to regional haze
Public Utilities, Commitments And Contingencies [Line Items]
Number of states to address regional haze (in states) | state					50
Potential to emit tons per year of visibility impairing pollution (in tons, more than) | T	250
Maximum | PNM | San Juan Generating Station and Four Corners
Public Utilities, Commitments And Contingencies [Line Items]
Government standard emission limit (in ozone parts per million) | parts_per_billion		75	75	70

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Commitments and Contingencies - Coal Supply (Details) - USD ($)	1 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2020	Sep. 30, 2021	Dec. 31, 2020	Dec. 31, 2019	Sep. 30, 2020	Jan. 31, 2016
Public Utilities, Commitments And Contingencies [Line Items]
Other current assets	$ 64,549,000	$ 57,484,000	$ 64,549,000
PNM
Public Utilities, Commitments And Contingencies [Line Items]
Other current assets	51,908,000	49,501,000	51,908,000
PNM | Loss on long-term purchase commitment | Surface
Public Utilities, Commitments And Contingencies [Line Items]
Loss contingency accrual	71,700,000	68,300,000	71,700,000
PNM | Loss on long-term purchase commitment | Underground
Public Utilities, Commitments And Contingencies [Line Items]
Loss contingency accrual	26,100,000	27,500,000	26,100,000
PNM | Loss on long-term purchase commitment | San Juan Generating Station | Surface
Public Utilities, Commitments And Contingencies [Line Items]
Estimate of possible loss		75,400,000
PNM | Loss on long-term purchase commitment | San Juan Generating Station | Underground
Public Utilities, Commitments And Contingencies [Line Items]
Estimate of possible loss		35,100,000
Coal supply | Four Corners
Public Utilities, Commitments And Contingencies [Line Items]
Payments for relief from obligations		75,000,000
Coal supply | PNM | San Juan Generating Station
Public Utilities, Commitments And Contingencies [Line Items]
Other current assets	26,300,000	21,900,000	26,300,000
Coal supply | NM Capital | San Juan Generating Station
Public Utilities, Commitments And Contingencies [Line Items]
Requirement to post reclamation bonds		118,700,000
Cash used to support bank letter or credit arrangement		30,300,000				$ 30,300,000
Increase in coal mine decommissioning liability | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory disallowance, additional amount recorded				$ 800,000
Increase in coal mine decommissioning liability | PNM | Surface
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory disallowance, additional amount recorded	3,600,000
Decrease in coal mine decommissioning liability | PNM | Underground
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory disallowance, additional amount recorded	$ 100,000
Decrease in coal mine decommissioning liability | PNM | Four Corners
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory disallowance, additional amount recorded			2,500,000
Mine Reclamation Trust | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Required contribution to reclamation trust, current fiscal year		4,800,000
Reclamation trust funding, year 2		6,200,000
Reclamation trust funding, year 3		0
Four Corners CSA | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Other commitment, due in first year					$ 2,000,000
Other commitment, due in second year					$ 2,200,000
Other commitment, due in third year		2,100,000
Other commitment, due in fourth year		2,100,000
Other commitment, due in fifth year		$ 2,100,000
San Juan Generating Station | Loss on long-term purchase commitment | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Annual funding post-term reclamation trust			$ 3,200,000

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Commitments and Contingencies - Royalty Rates, Tax Assessment, Insurance and Other Matters (Details)	1 Months Ended	9 Months Ended
	Sep. 30, 2012 landowner	Sep. 30, 2021 USD ($) plaintiff lawsuit generating_unit shareholder	Dec. 01, 2015 Allotment_Parcel	Jul. 13, 2015 a	Jan. 22, 2015 Allotment_Parcel	Aug. 31, 2013
Continuous Highwall Mining | San Juan Generating Station
Public Utilities, Commitments And Contingencies [Line Items]
Proposed retroactive surface mining royalty rate						12.50%
Surface mining royalty rate applied		8.00%
Estimated underpaid surface mining royalties under proposed rate change		$ 5,000,000
PNM's share estimated underpaid surface mining royalties under proposed rate change		46.30%
Merger-Related Litigation
Public Utilities, Commitments And Contingencies [Line Items]
Number of shareholders involved in lawsuit | shareholder		6
Number of lawsuits for the Southern District of New York | lawsuit		5
Number of lawsuits filed for the Eastern District of New York | lawsuit		1
Number of plaintiffs who filed notices of voluntary dismissal | plaintiff		5
PNM | Navajo Nation Allottee Matters
Public Utilities, Commitments And Contingencies [Line Items]
Number of landowners involved in the appeal | landowner	43
Number of allotments where landowners are revoking rights of way renewal consents (in allotment parcels) | Allotment_Parcel			2		10
Area of land (in acres) | a				15.49
Number of allotment parcels at issue that are not to be condemned | Allotment_Parcel			2
Number of allotment parcels at issue | Allotment_Parcel			5
PNM | Palo Verde Nuclear Generating Station | Nuclear plant
Public Utilities, Commitments And Contingencies [Line Items]
Ownership percentage in nuclear reactor		10.20%
Number of units | generating_unit		3
Maximum potential assessment per incident		$ 42,100,000
Annual payment limitation related to incident		6,200,000
Aggregate amount of all risk insurance		2,800,000,000
Maximum amount under Nuclear Electric Insurance Limited		5,400,000
PNM | Maximum | Palo Verde Nuclear Generating Station | Nuclear plant
Public Utilities, Commitments And Contingencies [Line Items]
Liability insurance coverage		13,500,000,000
Liability insurance coverage sublimit		2,250,000,000
Texas-New Mexico Power Company
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory assets		800,000
Commercial providers | PNM | Palo Verde Nuclear Generating Station | Nuclear plant
Public Utilities, Commitments And Contingencies [Line Items]
Liability insurance coverage		450,000,000
Industry Wide Retrospective Assessment Program | PNM | Palo Verde Nuclear Generating Station | Nuclear plant
Public Utilities, Commitments And Contingencies [Line Items]
Liability insurance coverage		$ 13,100,000,000

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Regulatory and Rate Matters - PNM (Details)						3 Months Ended		9 Months Ended		12 Months Ended
	Jun. 01, 2021 USD ($)	Apr. 15, 2021 USD ($) GWh	Jan. 29, 2021	Jan. 01, 2021 USD ($)	Apr. 15, 2020 USD ($) MMBTU meter	Sep. 30, 2021 USD ($) MW	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($) MW	Sep. 30, 2020 USD ($)	Dec. 31, 2020 USD ($) GWh	Jul. 29, 2020 MW
Public Utilities, Commitments And Contingencies [Line Items]
Excess return on jurisdictional equity that would require refund						0.50%		0.50%
PNM
Public Utilities, Commitments And Contingencies [Line Items]
Solar generation capacity (in megawatts) | MW											650
Renewable Portfolio Standard | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Number of megawatts of Solar PV facilities | MW						158		158
Current output in the geothermal facility (in megawatts) | MW						11		11
Solar generation capacity (in megawatts) | MW						190.8		190.8
Energy Efficiency and Load Management Program | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Energy efficiency and load management programs targeted energy savings (in Gigawatts) | MMBTU					80
Program costs related to energy efficiency, in year two					$ 31,400,000
Program costs related to energy efficiency, in year three					31,000,000
Program costs related to energy efficiency, in year four					$ 29,600,000
Number of AMI meters to be installed | meter					5,000
Program costs related to meter installation					$ 2,900,000
Integrated Resource Plan, 2011 | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Frequency of IRP filings								3 years
Planning period covered of IRP								20 years
Integrated Resource Plan, 2020 | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Planning period covered of IRP			20 years
NMPRC
Public Utilities, Commitments And Contingencies [Line Items]
Action plan, covered period								4 years
NMPRC | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Proposed revision to rider that will allow for recovery	$ 66,900,000			$ 67,800,000
NMPRC | Renewable Energy Rider | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Renewable energy procurement plan, approved recovery, amount				65,500,000
Recorded revenues from renewable rider						$ 13,000,000	$ 12,000,000	$ 44,400,000	$ 42,300,000
NMPRC | Renewable Energy Rider, Sky Blue Energy Program | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Proposed revision to rider that will allow for recovery				$ 2,300,000
Maximum | Renewable Portfolio Standard | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Reasonable cost threshold in megawatts per hour						$ 60		$ 60
Minimum | Renewable Portfolio Standard | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Profit incentive sliding scale multiplier					0.071					0.071
Energy efficiency and load management programs targeted energy savings (in Gigawatts) | MMBTU					80
New Mexico Wind | Renewable Portfolio Standard 2014 | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Number of megawatts for wind energy | MW								200
Red Mesa Wind | Renewable Portfolio Standard 2014 | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Number of megawatts for wind energy | MW								102
La Joya Wind | Renewable Portfolio Standard | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Number of megawatts for wind energy | MW								140
Disincentives and Incentives Added | 2017 Energy Efficiency and Load Management Program | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Energy efficiency and load management programs profit incentive, minimum										$ 1,800,000
Energy efficiency and load management programs targeted energy savings (in Gigawatts) | GWh										59
Energy efficiency and load management programs additional incentive targeted energy savings (in Gigawatts) | GWh										68
Disincentives and Incentives Added | 2020 Energy Efficiency Annual Report | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Energy efficiency and load management programs additional incentive targeted energy savings (in Gigawatts) | GWh		87
Energy efficiency and load management programs		$ 800,000

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Regulatory and Rate Matters - SJGS, Fours Corners and PVNGS Leased Interest Abandonment Applications (Details) $ in Thousands						1 Months Ended	3 Months Ended	9 Months Ended
	Apr. 02, 2021 lease MW	Feb. 03, 2021	Jan. 08, 2021 USD ($)	Nov. 01, 2020 USD ($)	Jul. 01, 2019 USD ($)	Nov. 30, 2020 USD ($)	Sep. 30, 2021 USD ($) MW power_purchase_agreement	Sep. 30, 2021 USD ($) MW	Oct. 01, 2021 MW	Jul. 28, 2021 MW	Jul. 22, 2021 resource_project MW	Jun. 23, 2021 MW	May 27, 2021 MW	Mar. 12, 2021 MW	Feb. 08, 2021 MW	Jan. 28, 2021 MW	Dec. 31, 2020 USD ($)	Dec. 18, 2020 USD ($)	Nov. 13, 2020 MW	Sep. 28, 2020 USD ($)	Jul. 29, 2020 MW	Mar. 31, 2020 USD ($)	Feb. 21, 2020 USD ($)
Public Utilities, General Disclosures [Line Items]
Number of purchase power agreements | power_purchase_agreement							3
Regulatory time frame for proposed PPAs and battery storage agreements	6 months
Ownership							50.00%	50.00%
Regulatory assets							$ 544,432	$ 544,432									$ 557,790
Regulatory liabilities							$ 855,855	855,855									850,228
COVID-19
Public Utilities, General Disclosures [Line Items]
Temporary mandatory moratorium on disconnection period		100 days
Disconnection transition period		90 days
Facebook Data Center
Public Utilities, General Disclosures [Line Items]
Solar generation capacity (in megawatts) | MW										190					190
Number of megawatts in battery storage facilities (in megawatts) | MW										100		100			100
Solar generation capacity expected to be operational (in megawatts) | MW										50					50
Number of megawatts in battery storage facilities approved (in megawatts) | MW										50
Facebook Data Center | Subsequent event
Public Utilities, General Disclosures [Line Items]
Number of megawatts in battery storage facilities (in megawatts) | MW									100
Number of megawatts in battery storage facilities approved (in megawatts) | MW									50
PNM
Public Utilities, General Disclosures [Line Items]
Solar generation capacity (in megawatts) | MW																					650
Number of megawatts in battery storage facilities (in megawatts) | MW																					300
Number of additional approved replacement resource projects | resource_project											2
Number of purchase power agreements | power_purchase_agreement							3
Number of leases under which lease term was extended | lease	5
Regulatory assets							$ 452,596	452,596									457,953
Regulatory liabilities							661,272	661,272									664,873
Solar generation capacity related to unexecuted transmission service agreement (in megawatts) | MW														145
PNM | Four Corners
Public Utilities, General Disclosures [Line Items]
Request issuance of energy transition bonds			$ 300,000
Forecasted undepreciated investment			272,000
Plant decommissioning and coal mine reclamation costs			4,600
Upfront financing costs			7,300
Proceeds from securitization bonds			$ 16,500
Solar generation capacity (in megawatts) | MW																200
Payments for relief from obligations				$ 75,000		$ 15,000
Final payment for relief from obligations						60,000
Initial payment for relief from obligations						$ 15,000
PNM | Four Corners | PNM
Public Utilities, General Disclosures [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners				13.00%
PNM | COVID-19 | COVID-19 Costs Savings
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities																	900
PNM | Deferred COVID-19 Costs | COVID-19
Public Utilities, General Disclosures [Line Items]
Regulatory assets							$ 13,200	$ 13,200									8,800
PNM | NMPRC
Public Utilities, General Disclosures [Line Items]
Solar generation capacity, amount requested for approval to abandon (in megawatts) | MW	114
PNM | Leased Interest Termination on January 15, 2023
Public Utilities, General Disclosures [Line Items]
Number of leases under which lease term was extended | lease	4
PNM | Leased Interest Termination on January 15, 2023 | NMPRC
Public Utilities, General Disclosures [Line Items]
Solar generation capacity (in megawatts) | MW	104
PNM | Leased Interest Termination on January 15, 2024 | NMPRC
Public Utilities, General Disclosures [Line Items]
Solar generation capacity (in megawatts) | MW	10
PNM | Replacement Resource Portfolio One
Public Utilities, General Disclosures [Line Items]
Solar generation capacity (in megawatts) | MW	150										200								200
Number of megawatts in battery storage facilities (in megawatts) | MW	40										100								100
Number of megawatts available in battery storage facilities (in megawatts) | MW											50
PNM | Replacement Resource Portfolio Two
Public Utilities, General Disclosures [Line Items]
Solar generation capacity (in megawatts) | MW											300		100						100
Number of megawatts in battery storage facilities (in megawatts) | MW	100										150		30						30
Number of megawatts available in battery storage facilities (in megawatts) | MW											150
Number of megawatts available in solar facilities (in megawatts) | MW											150
PNM | Replacement Resource Portfolio Three
Public Utilities, General Disclosures [Line Items]
Solar generation capacity (in megawatts) | MW	300
Number of megawatts in battery storage facilities (in megawatts) | MW	150
PNM | Transportation Electrification Program
Public Utilities, General Disclosures [Line Items]
Expected budgeted expenditures																		$ 8,400
Budget flexibility																		25.00%
Budget portion dedicated to low and moderate income customers																		25.00%
PNM | Portfolio One
Public Utilities, General Disclosures [Line Items]
Number of megawatts available in purchase power agreement | MW							85	85
PNM | Portfolio Two
Public Utilities, General Disclosures [Line Items]
Number of megawatts available in purchase power agreement | MW							150	150
PNM | Portfolio Three
Public Utilities, General Disclosures [Line Items]
Number of megawatts available in purchase power agreement | MW							40	40
PNMR Development
Public Utilities, General Disclosures [Line Items]
Solar generation capacity (in megawatts) | MW							130	130
Ownership							50.00%	50.00%
San Juan Generating Station
Public Utilities, General Disclosures [Line Items]
Estimated costs of replacement resources																				$ 8,100
San Juan Generating Station | Other deferred credits
Public Utilities, General Disclosures [Line Items]
Restructuring reserve																	38,100
San Juan Generating Station | Employee Severance
Public Utilities, General Disclosures [Line Items]
Restructuring reserve																						$ 9,400
San Juan Generating Station | PNM
Public Utilities, General Disclosures [Line Items]
Request issuance of energy transition bonds					$ 361,000
Forecasted undepreciated investment					283,000																		$ 361,000
Plant decommissioning and coal mine reclamation costs					28,600
Upfront financing costs					9,600
Severance costs					20,000
Proceeds from securitization bonds					$ 19,800
San Juan Generating Station | PNM | Other deferred credits
Public Utilities, General Disclosures [Line Items]
Restructuring reserve																	$ 36,800
San Juan Generating Station | PNM | Employee Severance
Public Utilities, General Disclosures [Line Items]
Restructuring reserve																						8,100
San Juan Generating Station | PNM | Other Restructuring
Public Utilities, General Disclosures [Line Items]
Restructuring reserve																						8,900
San Juan Generating Station | PNM | Economic Development and Workforce Training Costs
Public Utilities, General Disclosures [Line Items]
Restructuring reserve																						$ 19,800

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Regulatory and Rate Matters - Community Solar (Details)	Sep. 30, 2021 MW
Community Solar Act
Public Utilities, General Disclosures [Line Items]
Solar generation capacity (in megawatts)	200

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Regulatory and Rate Matters - San Juan Generating Station Unit 1 Outage (Details) - San Juan Generating Station $ in Millions	Sep. 30, 2021 USD ($)
San Juan Generating Station Owners | Insurance Deductible
Public Utilities, Commitments And Contingencies [Line Items]
Estimate of possible loss	$ 2.0
Public Service Company of New Mexico | Insurance Deductible
Public Utilities, Commitments And Contingencies [Line Items]
Estimate of possible loss	$ 1.0
Public Service Company of New Mexico | San Juan Generating Station Unit 1
Public Utilities, Commitments And Contingencies [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners	50.00%

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Regulatory and Rate Matters - TNMP Narrative (Details) - TNMP $ in Millions						1 Months Ended		9 Months Ended
	Jul. 01, 2021 USD ($)	Apr. 05, 2021 USD ($)	Jun. 26, 2020 USD ($)	Apr. 14, 2020 USD ($)	Apr. 06, 2020 USD ($)	Oct. 31, 2019 USD ($)	Aug. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)	Sep. 30, 2021 USD ($)	Jul. 28, 2021 USD ($)	May 27, 2021 USD ($)	Mar. 01, 2021 USD ($)	Dec. 31, 2020 USD ($)	Oct. 02, 2020 USD ($)	Mar. 30, 2020 MWh	Mar. 01, 2020 USD ($)	Dec. 31, 2019 USD ($)
Public Utilities, Commitments And Contingencies [Line Items]
Requested increase in annual distribution revenue		$ 14.0			$ 14.7
Incremental distribution investments					$ 149.2
Annual distribution revenue requirement			$ 14.3
Increase in revenue base rate		$ 104.5
Collection of increase in annual distribution revenues	$ 13.5
Energy efficiency cost recovery, requested change amount											$ 7.2	$ 5.9				$ 5.9
Energy efficiency cost recovery, requested bonus										$ 2.3	$ 2.3	$ 1.0				$ 0.8
Rider charge from electricity relief program (per MWh) | MWh															0.33
Proceeds from short-term debt				$ 0.5
Public utilities, estimate of possible upgrades														$ 46.0
PUCT
Public Utilities, Commitments And Contingencies [Line Items]
Public utilities, costs of deployment								$ 9.0
COVID-19
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory liability													$ 0.1
Other COVID-19 related costs									$ 0.9				$ 0.7
2018 TNMP Rate Case
Public Utilities, Commitments And Contingencies [Line Items]
Recovery of costs incurred						$ 3.3	$ 3.8
Recovery costs collection period							3 years
Write off of regulatory disallowance																	$ 0.5

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Regulatory and Rate Matters - Transmission Cost of Service Rates (Details) - PUCT - TNMP - USD ($) $ in Millions	Sep. 20, 2021	Mar. 12, 2021	Oct. 07, 2020
Public Utilities, General Disclosures [Line Items]
Approved Increase in Rate Base	$ 41.2	$ 112.6	$ 10.8
Annual Increase in Revenue	$ 6.3	$ 14.1	$ 2.0

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Lease Commitments - Narrative (Details) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Apr. 30, 2021 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Apr. 02, 2021 lease	Dec. 31, 2020 USD ($)	Jan. 15, 2016 lease	Jan. 15, 2015 lease
Operating Leased Assets [Line Items]
Operating lease, payments to lessor upon occurrence of certain events		$ 148.4		$ 148.4
Unamortized cost, right-of-way lease payments		54.0		54.0			$ 55.8
Operating lease, right-of-use assets, amortization expense		0.9	$ 0.9	2.8	$ 2.8
Operating leases, capitalized financing costs, investing activities				2.3	2.6
Finance leases, capitalized financing costs, investing activities				3.2	1.8
Lessee, operating lease, unguaranteed residual value		26.3		26.3
PNM
Operating Leased Assets [Line Items]
Number of leases under which lease term was extended | lease						5
Operating leases, capitalized financing costs, investing activities				0.6	0.8
Finance leases, capitalized financing costs, investing activities				1.2	0.7
Lessee, operating lease, unguaranteed residual value		11.3		11.3
PNM | Palo Verde Nuclear Generating Station, Unit 1 and 4 Leases
Operating Leased Assets [Line Items]
Number of leases, expiring | lease									4
Number of leases under which lease term was extended | lease									4
Annual lease payments during renewal period				16.5
PNM | Palo Verde Nuclear Generating Station, Unit 2 Leases
Operating Leased Assets [Line Items]
Number of leases, expiring | lease								4
Number of leases under which lease term was extended | lease								1
Annual lease payments during renewal period				1.6
PNM | Navajo Nation
Operating Leased Assets [Line Items]
Annual lease payments				6.0
Right-of-way lease payments	$ 7.3
TNMP
Operating Leased Assets [Line Items]
Operating leases, capitalized financing costs, investing activities				1.6	1.8
Finance leases, capitalized financing costs, investing activities				2.0	$ 1.1
Lessee, operating lease, unguaranteed residual value		15.0		15.0
Equipment
Operating Leased Assets [Line Items]
Operating lease, residual value of leased asset		2.3		2.3
Equipment | PNM
Operating Leased Assets [Line Items]
Operating lease, residual value of leased asset		0.8		0.8
Equipment | TNMP
Operating Leased Assets [Line Items]
Operating lease, residual value of leased asset		$ 1.5		$ 1.5

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Lease Commitments - Operating Lease Balance Sheet Information (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Operating leases:
Operating lease assets, net of amortization	$ 85,956	$ 105,133
Current portion of operating lease liabilities	28,230	27,460
Long-term portion of operating lease liabilities	55,106	81,065
PNM
Operating leases:
Operating lease assets, net of amortization	79,808	97,461
Current portion of operating lease liabilities	26,166	25,130
Long-term portion of operating lease liabilities	51,233	75,941
TNMP
Operating leases:
Operating lease assets, net of amortization	5,778	7,206
Current portion of operating lease liabilities	1,988	2,193
Long-term portion of operating lease liabilities	$ 3,579	$ 4,779

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Lease Commitments - Finance Lease Balance Sheet Information (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Financing leases:
Non-utility property	$ 30,328	$ 25,055
Accumulated depreciation	(8,185)	(4,383)
Non-utility property, net	22,143	20,672
Other current liabilities	5,602	4,470
Other deferred credits	16,373	15,972
PNM
Financing leases:
Non-utility property	14,276	11,453
Accumulated depreciation	(3,838)	(2,044)
Non-utility property, net	10,438	9,409
Other current liabilities	2,620	1,993
Other deferred credits	7,639	7,176
TNMP
Financing leases:
Non-utility property	15,722	13,299
Accumulated depreciation	(4,185)	(2,241)
Non-utility property, net	11,537	11,058
Other current liabilities	2,897	2,397
Other deferred credits	$ 8,649	$ 8,669

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Lease Commitments - Schedule of Weighted Average Remaining Lease Terms and Discount Rates (Details)	Sep. 30, 2021
Weighted average remaining lease term (years):
Operating leases	5 years 7 months 24 days
Financing leases	4 years 3 months 25 days
Weighted average discount rate:
Operating leases	3.98%
Financing leases	2.67%
PNM
Weighted average remaining lease term (years):
Operating leases	5 years 9 months 29 days
Financing leases	4 years 3 months 21 days
Weighted average discount rate:
Operating leases	3.99%
Financing leases	2.62%
TNMP
Weighted average remaining lease term (years):
Operating leases	3 years 29 days
Financing leases	4 years 4 months 6 days
Weighted average discount rate:
Operating leases	3.97%
Financing leases	2.72%

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Lease Commitments - Components of Lease Expense (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Lease, Cost [Line Items]
Operating lease cost:	$ 7,192	$ 7,545	$ 22,006	$ 22,938
Amounts capitalized	(716)	(825)	(2,264)	(2,599)
Total operating lease expense	6,476	6,720	19,742	20,339
Financing lease cost:
Amortization of right-of-use assets	1,372	893	3,802	2,187
Interest on lease liabilities	145	134	426	358
Amounts capitalized	(1,161)	(733)	(3,202)	(1,787)
Total financing lease expense	356	294	1,026	758
Variable lease expense	106	63	274	158
Short-term lease expense	1,578	22	1,857	183
Total lease expense for the period	8,516	7,099	22,899	21,438
Cooling Towers
Financing lease cost:
Short-term lease expense	1,400		1,400
Increase reimbursements	900		900
PNM
Lease, Cost [Line Items]
Operating lease cost:	6,569	6,798	20,020	20,538
Amounts capitalized	(199)	(248)	(645)	(786)
Total operating lease expense	6,370	6,550	19,375	19,752
Financing lease cost:
Amortization of right-of-use assets	657	435	1,793	1,022
Interest on lease liabilities	66	58	193	156
Amounts capitalized	(452)	(281)	(1,235)	(682)
Total financing lease expense	271	212	751	496
Variable lease expense	106	63	274	158
Short-term lease expense	1,572	16	1,821	176
Total lease expense for the period	8,319	6,841	22,221	20,582
TNMP
Lease, Cost [Line Items]
Operating lease cost:	594	685	1,880	2,205
Amounts capitalized	(517)	(577)	(1,618)	(1,812)
Total operating lease expense	77	108	262	393
Financing lease cost:
Amortization of right-of-use assets	693	439	1,944	1,110
Interest on lease liabilities	78	74	230	198
Amounts capitalized	(709)	(452)	(1,967)	(1,105)
Total financing lease expense	62	61	207	203
Variable lease expense	0	0	0	0
Short-term lease expense	2	4	6	5
Total lease expense for the period	$ 141	$ 173	$ 475	$ 601

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Lease Commitments - Schedule of Supplemental Cash Flows Related to Leases (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$ 25,897	$ 26,708
Operating cash flows from financing leases	92	94
Finance cash flows from financing leases	920	646
Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	317	0
Financing leases	5,567	11,985
PNM
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	25,511	25,804
Operating cash flows from financing leases	65	58
Finance cash flows from financing leases	621	378
Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	0	0
Financing leases	2,898	5,635
TNMP
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	262	483
Operating cash flows from financing leases	24	32
Finance cash flows from financing leases	234	215
Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	317	0
Financing leases	$ 2,642	$ 6,309

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Lease Commitments - Schedule of Future Expected Lease Payments (Details) $ in Thousands	Sep. 30, 2021 USD ($)
Financing
Remainder of 2021	$ 1,532
2022	5,980
2023	5,607
2024	4,421
2025	2,710
Later years	2,752
Total minimum lease payments	23,002
Less: Imputed interest	1,027
Lease liabilities as of September 30, 2021	21,975
Operating
Remainder of 2021	935
2022	28,467
2023	19,665
2024	8,833
2025	7,685
Later years	27,816
Total minimum lease payments	93,401
Less: Imputed interest	10,065
Lease liabilities as of September 30, 2021	83,336
PNM
Financing
Remainder of 2021	709
2022	2,767
2023	2,649
2024	1,972
2025	1,164
Later years	1,335
Total minimum lease payments	10,596
Less: Imputed interest	337
Lease liabilities as of September 30, 2021	10,259
Operating
Remainder of 2021	334
2022	26,266
2023	17,735
2024	7,908
2025	6,946
Later years	27,520
Total minimum lease payments	86,709
Less: Imputed interest	9,310
Lease liabilities as of September 30, 2021	77,399
TNMP
Financing
Remainder of 2021	800
2022	3,125
2023	2,906
2024	2,438
2025	1,545
Later years	1,417
Total minimum lease payments	12,231
Less: Imputed interest	685
Lease liabilities as of September 30, 2021	11,546
Operating
Remainder of 2021	538
2022	1,990
2023	1,750
2024	877
2025	702
Later years	76
Total minimum lease payments	5,933
Less: Imputed interest	366
Lease liabilities as of September 30, 2021	$ 5,567

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Income Taxes (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended	12 Months Ended
	Jun. 30, 2021	Sep. 30, 2021	Mar. 31, 2018	Sep. 30, 2021	Dec. 31, 2017	Dec. 31, 2020
Income Tax Contingency [Line Items]
Accelerated refund application amount of AMT tax, CARES act						$ 5.2
Deferred tax assets, tax deferred expense, payroll taxes, CARES Act						$ 7.0
Refund amount of AMT tax, CARES act	$ 5.2
Deferred federal, state and local, income tax expense (benefit)				$ 24.5
Effective tax rate				13.08%
Tax benefits related to stock awards		$ 0.1		$ 0.8
Tax benefits on merger-related costs		0.3		1.8
PNM
Income Tax Contingency [Line Items]
Deferred federal, state and local, income tax expense (benefit)				$ 15.2
Effective tax rate				15.43%
Tax benefits related to stock awards		0.1		$ 0.6
Tax benefits on merger-related costs		0.1		0.1
TNMP
Income Tax Contingency [Line Items]
Deferred federal, state and local, income tax expense (benefit)				$ 9.3
Effective tax rate				11.12%
Tax benefits related to stock awards		0.1		$ 0.2
Tax benefits on merger-related costs		$ 0.1		$ 0.1
NMPRC
Income Tax Contingency [Line Items]
Period of time for proposed return to customers the benefit of the reduction in federal corporate income tax rate					23 years
Period of time for proposed return to customers the benefit of the reduction in New Mexico's corporate income tax rate			3 years

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Related Party Transactions (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Related Party Transaction [Line Items]
Ownership	50.00%		50.00%
Services billings: | PNMR to PNM
Related Party Transaction [Line Items]
Amount of related party transaction	$ 23,617	$ 24,204	$ 75,992	$ 70,848
Services billings: | PNMR to TNMP
Related Party Transaction [Line Items]
Amount of related party transaction	9,187	9,645	29,687	28,075
Services billings: | PNM to TNMP
Related Party Transaction [Line Items]
Amount of related party transaction	107	106	319	295
Services billings: | TNMP to PNMR
Related Party Transaction [Line Items]
Amount of related party transaction	0	35	24	106
Services billings: | PNMR to NMRD
Related Party Transaction [Line Items]
Amount of related party transaction	55	74	165	199
Renewable energy purchases: | PNM from NMRD
Related Party Transaction [Line Items]
Amount of related party transaction	3,384	3,723	9,473	7,646
Interconnection billings: | PNM from NMRD
Related Party Transaction [Line Items]
Amount of related party transaction	225	0	225	350
Interconnection billings: | PNM to PNMR
Related Party Transaction [Line Items]
Amount of related party transaction	0	0	0	0
Interconnection billings: | NMRD to PNM
Related Party Transaction [Line Items]
Amount of related party transaction	0	0	1,276	0
Interest billings: | PNMR to PNM
Related Party Transaction [Line Items]
Amount of related party transaction	0	0	0	6
Interest billings: | PNMR to TNMP
Related Party Transaction [Line Items]
Amount of related party transaction	0	0	0	2
Interest billings: | PNM to PNMR
Related Party Transaction [Line Items]
Amount of related party transaction	36	60	108	218
Income tax sharing payments: | PNMR to PNM
Related Party Transaction [Line Items]
Amount of related party transaction	0	0	0	0
Income tax sharing payments: | TNMP to PNMR
Related Party Transaction [Line Items]
Amount of related party transaction	$ 0	$ 0	$ 0	$ 0

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Equity Method Investment (Details)	1 Months Ended	9 Months Ended
	Feb. 28, 2021 USD ($)	Sep. 30, 2021 USD ($) MW	Sep. 30, 2020 USD ($)
Business Acquisition [Line Items]
Ownership		50.00%
Distributions from NMRD		$ 572,000	$ 0
NMRD
Business Acquisition [Line Items]
Renewable energy capacity in operating (in mw) | MW		135.1
PNMR Development
Business Acquisition [Line Items]
Ownership		50.00%
PNMR Development | NMRD
Business Acquisition [Line Items]
Ownership		50.00%
Contribution to construction activities		$ 0	$ 23,300,000
Distributions from NMRD	$ 3,000,000
Earnings from equity method investments, net of dividends or distributions	2,400,000
Proceeds from equity method investment, distribution, return of capital	$ 600,000
AEP OnSite Partners | NMRD
Business Acquisition [Line Items]
Ownership		50.00%

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Equity Method Investment - Summarized Financial Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Results of Operations
Operating revenues	$ 554,551	$ 472,465	$ 1,345,798	$ 1,163,736
Financial Position
Construction work in progress	350,090		350,090		$ 218,719
Assets	8,256,070	7,742,112	8,256,070	7,742,112	7,939,854
Total stockholders' equity	2,144,950		2,144,950		2,049,465
NMRD
Results of Operations
Operating revenues	3,543	3,462	10,179	7,769
Operating expenses	2,422	2,100	7,360	5,152
Net Earnings Attributable to PNMR	1,121	$ 1,362	2,819	$ 2,617
Financial Position
Current assets	9,164		9,164		8,046
Construction work in progress	168,053		168,053		172,585
Non-current assets	2,448		2,448		1,900
Assets	179,665		179,665		182,531
Current liabilities	1,166		1,166		841
Non-current liabilities	370		370		380
Total stockholders' equity	$ 178,129		$ 178,129		$ 181,310

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Goodwill (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020	Sep. 30, 2020	Apr. 01, 2018
Goodwill [Line Items]
Goodwill	$ 278,297	$ 278,297	$ 278,297
PNM
Goodwill [Line Items]
Goodwill	51,632	51,632		$ 51,600
Goodwill fair value exceeded by its carrying value				19.00%
TNMP
Goodwill [Line Items]
Goodwill	$ 226,665	$ 226,665		$ 226,700
Goodwill fair value exceeded by its carrying value				38.00%

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Merger (Details) - Forecast - Merger Agreement - USD ($) $ / shares in Units, $ in Millions		3 Months Ended
	Jan. 20, 2022	Dec. 31, 2022
Business Acquisition [Line Items]
Business combination, cash right per common share (in dollars per share)		$ 50.30
Termination fees	$ 130.0
Out-of-pocket fees and expenses reimbursement		$ 10.0
Avangrid
Business Acquisition [Line Items]
Termination fees		$ 184.0