Texas New Mexico Power 10-Q 28 Apr 22 2022 Q1 Quarterly report Financial data

Cover Page

Cover Page - shares	3 Months Ended
	Mar. 31, 2022	Apr. 21, 2022
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2022
Document Transition Report	false
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		85,834,874
Entity Central Index Key	0001108426
Document Fiscal Year Focus	2022
Current Fiscal Year End Date	--12-31
Document Fiscal Period Focus	Q1
Amendment Flag	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		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		6,358
Entity Central Index Key	0000022767
Current Fiscal Year End Date	--12-31

Condensed Consolidated Statemen

Condensed Consolidated Statements of Earnings - PNMR - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Cost of Revenue [Abstract]
Contracts with customers	$ 384,493	$ 346,585
Alternative revenue programs	(5,505)	(909)
Other electric operating revenue	65,130	19,031
Total electric operating revenues	444,118	364,707
Operating Expenses:
Administrative and general	55,861	59,465
Depreciation and amortization	75,764	69,874
Transmission and distribution costs	18,466	17,317
Taxes other than income taxes	23,979	22,593
Total operating expenses	376,050	321,541
Operating income	68,068	43,166
Other Income and Deductions:
Interest income	4,292	3,559
Gains (losses) on investment securities	(26,573)	968
Other income	4,330	4,252
Other (deductions)	(2,241)	(3,290)
Net other income and deductions	(20,192)	5,489
Interest Charges	26,220	25,884
Earnings before Income Taxes	21,656	22,771
Income Taxes	2,438	1,566
Net Earnings	19,218	21,205
(Earnings) Attributable to Valencia Non-controlling Interest	(3,095)	(3,494)
Preferred Stock Dividend Requirements	(132)	(132)
Net Earnings Available for PNM Common Stock	$ 15,991	$ 17,579
Income Loss From Continuing Operations Attributable To Parent Per Share [Abstract]
Basic (dollars per share)	$ 0.19	$ 0.20
Diluted (dollars per share)	0.19	0.20
Dividends Declared per Common Share (dollars per share)	$ 0.3475	$ 0.3275
Energy
Cost of Revenue [Abstract]
Total electric operating revenues	$ 444,118	$ 364,707
Operating Expenses:
Energy costs	168,414	115,396
Energy Production
Operating Expenses:
Energy costs	$ 33,566	$ 36,896

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Comprehensive Income - PNMR - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Comprehensive Income [Abstract]
Net Earnings	$ 19,218	$ 21,205
Unrealized Gains on Available-for-Sale Debt Securities:
Net change in unrealized holding (losses) arising during the period, net of income tax benefit of $1,657 and $845	(4,867)	(2,481)
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $375 and $919	(1,102)	(2,699)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience losses recognized as net periodic benefit cost, net of income tax (benefit) of $(451) and $(530)	1,325	1,557
Fair Value Adjustment for Cash Flow Hedges:
Change in fair market value, net of income tax (expense) of $0 and $(317)	0	930
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $0 and $158	0	(466)
Total Other Comprehensive Income (Loss)	(4,644)	(3,159)
Comprehensive Income	14,574	18,046
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(3,095)	(3,494)
Preferred Stock Dividend Requirements of Subsidiary	(132)	(132)
Comprehensive Income (Loss) Attributable to PNM	$ 11,347	$ 14,420

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Comprehensive Income - PNMR (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Comprehensive Income [Abstract]
Unrealized holding gains (losses) arising during the period, income tax (expense) benefit	$ 1,657	$ 845
Reclassification adjustment for (gains) losses included in net earnings, income tax expense (benefit)	375	919
Pension liability adjustment, income tax expense (benefit)	(451)	(530)
Change in fair market value, income tax (expense) benefit	0	(317)
Reclassification adjustment for (gains) losses included in net earnings, income tax expense (benefit)	$ 0	$ 158

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Cash Flows - PNMR - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net earnings	$ 19,218	$ 21,205
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	84,672	78,857
Deferred income tax expense	2,009	1,447
(Gains) losses on investment securities	26,486	(967)
Share-based Payment Arrangement, Noncash Expense	3,052	4,219
Allowance for equity funds used during construction	(2,668)	(2,621)
Other, net	708	3,234
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	21,169	17,205
Materials, supplies, and fuel stock	(5,183)	4,305
Other current assets	13,079	(18,978)
Other assets	(12,215)	6,561
Accounts payable	(15,905)	(9,647)
Accrued interest and taxes	909	76
Other current liabilities	(6,458)	(4,369)
Other liabilities	(12,263)	(14,050)
Net cash flows from operating activities	116,610	86,477
Cash Flows From Investing Activities:
Utility plant additions	(209,884)	(172,235)
Proceeds from sales of investment securities	125,246	123,596
Purchases of investment securities	(127,791)	(126,485)
Distributions from NMRD	0	572
Other, net	565	97
Net cash flows used in investing activities	(211,864)	(174,455)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings, net	23,300	165,500
Long-term borrowings	100,000	220,000
Repayment of long-term debt	0	(300,000)
Awards of common stock	(6,735)	(9,027)
Dividends paid	(29,960)	(28,243)
Valencia’s transactions with its owner	(4,232)	(5,243)
Transmission interconnection and security deposit arrangements	18,569	5,460
Refunds paid under transmission interconnection arrangements	(1,972)	(584)
Debt issuance costs and other, net	(431)	(292)
Net cash flows from financing activities	98,539	47,571
Change in Cash, Restricted Cash, and Equivalents	3,285	(40,407)
Cash, Restricted Cash, and Equivalents at Beginning of Period	1,104	47,928
Cash, Restricted Cash, and Equivalents at End of Period	4,389	7,521
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	21,682	23,317
Income taxes paid (refunded), net	(346)	0
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	$ 38,918	$ 49,092

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - PNMR - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 4,389	$ 1,104
Accounts receivable, net of allowance for credit losses of $6,392 and $7,265	116,015	123,292
Unbilled revenues	42,153	57,736
Other receivables	19,414	18,784
Materials, supplies, and fuel stock	70,244	65,061
Regulatory assets	18,597	14,785
Prepaid assets	25,149	37,325
Income taxes receivable	4,102	4,878
Other current assets	1,082	1,635
Total current assets	301,145	324,600
Other Property and Investments:
Investment securities	431,097	463,126
Equity investment in NMRD	89,344	89,158
Other investments	174	265
Non-utility property, net	24,420	25,439
Total other property and investments	545,035	577,988
Utility Plant:
Plant in service, held for future use, and to be abandoned	9,448,704	9,357,849
Less accumulated depreciation and amortization	3,003,558	2,952,743
Net plant in service and plant held for future use	6,445,146	6,405,106
Construction work in progress	313,901	248,856
Nuclear fuel, net of accumulated amortization of $47,131 and $41,181	99,381	98,937
Net utility plant	6,858,428	6,752,899
Deferred Charges and Other Assets:
Regulatory assets	511,639	514,258
Goodwill	278,297	278,297
Operating lease right-of-use assets, net of accumulated amortization	74,126	79,511
Other deferred charges	159,016	139,332
Total deferred charges and other assets	1,023,078	1,011,398
Assets	8,727,686	8,666,885
Current Liabilities:
Short-term debt	86,000	62,700
Current installments of long-term debt	179,419	179,339
Accounts payable	117,772	172,595
Customer deposits	5,364	5,095
Accrued interest and taxes	70,238	70,105
Regulatory liabilities	12,885	8,316
Operating lease liabilities	27,722	27,218
Dividends declared	29,960	132
Transmission interconnection arrangement liabilities	42,666	39,564
Other current liabilities	101,017	99,149
Total current liabilities	673,043	664,213
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	3,620,041	3,519,580
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	772,263	764,850
Regulatory liabilities	845,701	841,393
Asset retirement obligations	236,877	234,146
Accrued pension liability and postretirement benefit cost	15,772	19,057
Operating lease liabilities	47,369	55,993
Other deferred credits	335,291	333,195
Total deferred credits and liabilities	2,253,273	2,248,634
Total liabilities	6,546,357	6,432,427
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
PNM common stockholder’s equity:
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 85,834,874 shares)	1,425,574	1,429,257
Accumulated other comprehensive income (loss), net of income taxes	(76,580)	(71,936)
Retained earnings	766,538	810,203
Total PNM common stockholder’s equity	2,115,532	2,167,524
Non-controlling interest in Valencia	54,268	55,405
Total equity	2,169,800	2,222,929
Total liabilities and stockholders' equity	$ 8,727,686	$ 8,666,885

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets - PNMR (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Allowance for uncollectible accounts	$ 6,392	$ 7,265
Accumulated depreciation, nuclear fuel	$ 47,131	$ 41,181
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

Condensed Consolidated Statem_5

Condensed Consolidated Statements of Changes in Equity - PNMR - USD ($) $ in Thousands	Total	Total PNMR Common Stockholders’ Equity	Common Stock	AOCI	Retained Earnings	Non- controlling Interest in Valencia
Beginning balance at Dec. 31, 2020	$ 2,108,474	$ 2,049,465	$ 1,429,941	$ (79,183)	$ 698,707	$ 59,009
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings before subsidiary preferred stock dividends	21,205	17,711			17,711	3,494
Total other comprehensive income (loss)	(3,159)	(3,159)		(3,159)
Subsidiary preferred stock dividends	(132)	(132)			(132)
Dividends declared on common stock	(28,111)	(28,111)			(28,111)
Awards of common stock	(9,027)	(9,027)	(9,027)
Stock based compensation expense	4,219	4,219	4,219
Valencia’s transactions with its owner	(5,243)					(5,243)
Ending balance at Mar. 31, 2021	2,088,226	2,030,966	1,425,133	(82,342)	688,175	57,260
Beginning balance at Dec. 31, 2021	2,222,929	2,167,524	1,429,257	(71,936)	810,203	55,405
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings before subsidiary preferred stock dividends	19,218	16,123			16,123	3,095
Total other comprehensive income (loss)	(4,644)	(4,644)		(4,644)
Subsidiary preferred stock dividends	(132)	(132)			(132)
Dividends declared on common stock	(59,656)	(59,656)			(59,656)
Awards of common stock	(6,735)	(6,735)	(6,735)
Stock based compensation expense	3,052	3,052	3,052
Valencia’s transactions with its owner	(4,232)					(4,232)
Ending balance at Mar. 31, 2022	$ 2,169,800	$ 2,115,532	$ 1,425,574	$ (76,580)	$ 766,538	$ 54,268

Condensed Consolidated Statem_6

Condensed Consolidated Statements of Earnings - PNM - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Cost of Revenue [Abstract]
Contracts with customers	$ 384,493	$ 346,585
Alternative revenue programs	(5,505)	(909)
Other electric operating revenue	65,130	19,031
Total electric operating revenues	444,118	364,707
Operating Expenses:
Administrative and general	55,861	59,465
Depreciation and amortization	75,764	69,874
Transmission and distribution costs	18,466	17,317
Taxes other than income taxes	23,979	22,593
Total operating expenses	376,050	321,541
Operating income	68,068	43,166
Other Income and Deductions:
Interest income	4,292	3,559
Gains (losses) on investment securities	(26,573)	968
Other income	4,330	4,252
Other (deductions)	(2,241)	(3,290)
Net other income and deductions	(20,192)	5,489
Interest Charges	26,220	25,884
Earnings before Income Taxes	21,656	22,771
Income Taxes	2,438	1,566
Net Earnings	19,218	21,205
(Earnings) Attributable to Valencia Non-controlling Interest	(3,095)	(3,494)
Preferred Stock Dividend Requirements	(132)	(132)
Net Earnings Available for PNM Common Stock	15,991	17,579
Energy
Cost of Revenue [Abstract]
Total electric operating revenues	444,118	364,707
Operating Expenses:
Energy costs	168,414	115,396
Energy Production
Operating Expenses:
Energy costs	33,566	36,896
PNM
Cost of Revenue [Abstract]
Contracts with customers	275,644	251,206
Alternative revenue programs	(2,065)	976
Other electric operating revenue	65,130	19,031
Total electric operating revenues	338,709	271,213
Operating Expenses:
Administrative and general	50,347	47,134
Depreciation and amortization	45,790	41,949
Transmission and distribution costs	11,611	10,659
Taxes other than income taxes	13,565	12,639
Total operating expenses	293,693	238,163
Operating income	45,016	33,050
Other Income and Deductions:
Interest income	3,133	3,595
Gains (losses) on investment securities	(26,573)	968
Other income	3,048	2,708
Other (deductions)	(1,691)	(2,432)
Net other income and deductions	(22,083)	4,839
Interest Charges	14,572	12,893
Earnings before Income Taxes	8,361	24,996
Income Taxes	823	2,834
Net Earnings	7,538	22,162
(Earnings) Attributable to Valencia Non-controlling Interest	(3,095)	(3,494)
Net Earnings Attributable to PNM	4,443	18,668
Preferred Stock Dividend Requirements	(132)	(132)
Net Earnings Available for PNM Common Stock	4,311	18,536
PNM | Energy
Operating Expenses:
Energy costs	138,814	88,886
PNM | Energy Production
Operating Expenses:
Energy costs	$ 33,566	$ 36,896

Condensed Consolidated Statem_7

Condensed Consolidated Statements of Comprehensive Income (Loss) - PNM - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net Earnings	$ 19,218	$ 21,205
Unrealized Gains on Available-for-Sale Debt Securities:
Net change in unrealized holding (losses) arising during the period, net of income tax benefit of $1,657 and $845	(4,867)	(2,481)
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $375 and $919	(1,102)	(2,699)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience losses recognized as net periodic benefit cost, net of income tax (benefit) of $(451) and $(530)	1,325	1,557
Total Other Comprehensive Income (Loss)	(4,644)	(3,159)
Comprehensive Income	14,574	18,046
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(3,095)	(3,494)
Comprehensive Income (Loss) Attributable to PNM	11,347	14,420
PNM
Net Earnings	7,538	22,162
Unrealized Gains on Available-for-Sale Debt Securities:
Net change in unrealized holding (losses) arising during the period, net of income tax benefit of $1,657 and $845	(4,867)	(2,481)
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $375 and $919	(1,102)	(2,699)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience losses recognized as net periodic benefit cost, net of income tax (benefit) of $(451) and $(530)	1,325	1,557
Total Other Comprehensive Income (Loss)	(4,644)	(3,623)
Comprehensive Income	2,894	18,539
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(3,095)	(3,494)
Comprehensive Income (Loss) Attributable to PNM	$ (201)	$ 15,045

Condensed Consolidated Statem_8

Condensed Consolidated Statements of Comprehensive Income (Loss) - PNM (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Unrealized holding gains (losses) arising during the period, income tax (expense) benefit	$ 1,657	$ 845
Reclassification adjustment for (gains) losses included in net earnings, income tax expense (benefit)	375	919
Pension liability adjustment, income tax expense (benefit)	(451)	(530)
PNM
Unrealized holding gains (losses) arising during the period, income tax (expense) benefit	1,657	845
Reclassification adjustment for (gains) losses included in net earnings, income tax expense (benefit)	375	919
Pension liability adjustment, income tax expense (benefit)	$ (451)	$ (530)

Condensed Consolidated Statem_9

Condensed Consolidated Statements of Cash Flows - PNM - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net earnings	$ 19,218	$ 21,205
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	84,672	78,857
Deferred income tax expense	2,009	1,447
(Gains) losses on investment securities	26,486	(967)
Allowance for equity funds used during construction	(2,668)	(2,621)
Other, net	708	3,234
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	21,169	17,205
Materials, supplies, and fuel stock	(5,183)	4,305
Other current assets	13,079	(18,978)
Other assets	(12,215)	6,561
Accounts payable	(15,905)	(9,647)
Accrued interest and taxes	909	76
Other current liabilities	(6,458)	(4,369)
Other liabilities	(12,263)	(14,050)
Net cash flows from operating activities	116,610	86,477
Cash Flows From Investing Activities:
Utility plant additions	(209,884)	(172,235)
Proceeds from sales of investment securities	125,246	123,596
Purchases of investment securities	(127,791)	(126,485)
Other, net	565	97
Net cash flows used in investing activities	(211,864)	(174,455)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings (repayments), net	23,300	165,500
Dividends paid	(29,960)	(28,243)
Valencia’s transactions with its owner	(4,232)	(5,243)
Transmission interconnection and security deposit arrangements	18,569	5,460
Refunds paid under transmission interconnection arrangements	(1,972)	(584)
Debt issuance costs and other, net	(431)	(292)
Net cash flows from financing activities	98,539	47,571
Change in Cash, Restricted Cash, and Equivalents	3,285	(40,407)
Cash, Restricted Cash, and Equivalents at Beginning of Period	1,104	47,928
Cash, Restricted Cash, and Equivalents at End of Period	4,389	7,521
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	21,682	23,317
Income taxes paid (refunded), net	(346)	0
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	38,918	49,092
PNM
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net earnings	7,538	22,162
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	53,844	50,108
Deferred income tax expense	893	2,910
(Gains) losses on investment securities	26,486	(967)
Allowance for equity funds used during construction	(2,294)	(2,135)
Other, net	894	911
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	22,466	17,491
Materials, supplies, and fuel stock	(4,636)	4,341
Other current assets	11,418	(21,763)
Other assets	(11,065)	5,780
Accounts payable	(6,876)	(934)
Accrued interest and taxes	14,873	14,729
Other current liabilities	(4,879)	(1,911)
Other liabilities	(10,198)	(13,196)
Net cash flows from operating activities	98,464	77,526
Cash Flows From Investing Activities:
Utility plant additions	(96,359)	(88,198)
Proceeds from sales of investment securities	125,246	123,596
Purchases of investment securities	(127,791)	(126,485)
Other, net	565	97
Net cash flows used in investing activities	(98,339)	(90,990)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings (repayments), net	(2,700)	(10,000)
Dividends paid	(132)	(132)
Valencia’s transactions with its owner	(4,232)	(5,243)
Transmission interconnection and security deposit arrangements	12,170	3,810
Refunds paid under transmission interconnection arrangements	(1,972)	(584)
Debt issuance costs and other, net	(293)	87
Net cash flows from financing activities	2,841	(12,062)
Change in Cash, Restricted Cash, and Equivalents	2,966	(25,526)
Cash, Restricted Cash, and Equivalents at Beginning of Period	19	31,446
Cash, Restricted Cash, and Equivalents at End of Period	2,985	5,920
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	9,070	7,568
Income taxes paid (refunded), net	0	0
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	$ 26,620	$ 30,828

Condensed Consolidated Balanc_3

Condensed Consolidated Balance Sheets - PNM - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 4,389	$ 1,104
Accounts receivable, net of allowance for credit losses of $6,392 and $7,265	116,015	123,292
Unbilled revenues	42,153	57,736
Other receivables	19,414	18,784
Materials, supplies, and fuel stock	70,244	65,061
Regulatory assets	18,597	14,785
Prepaid assets	25,149	37,325
Income taxes receivable	4,102	4,878
Other current assets	1,082	1,635
Total current assets	301,145	324,600
Other Property and Investments:
Investment securities	431,097	463,126
Other investments	174	265
Non-utility property, net	24,420	25,439
Total other property and investments	545,035	577,988
Utility Plant:
Plant in service, held for future use, and to be abandoned	9,448,704	9,357,849
Less accumulated depreciation and amortization	3,003,558	2,952,743
Net plant in service and plant held for future use	6,445,146	6,405,106
Construction work in progress	313,901	248,856
Nuclear fuel, net of accumulated amortization of $47,131 and $41,181	99,381	98,937
Net utility plant	6,858,428	6,752,899
Deferred Charges and Other Assets:
Regulatory assets	511,639	514,258
Goodwill	278,297	278,297
Operating lease right-of-use assets, net of accumulated amortization	74,126	79,511
Other deferred charges	159,016	139,332
Total deferred charges and other assets	1,023,078	1,011,398
Assets	8,727,686	8,666,885
Current Liabilities:
Short-term debt	86,000	62,700
Current installments of long-term debt	179,419	179,339
Accounts payable	117,772	172,595
Customer deposits	5,364	5,095
Accrued interest and taxes	70,238	70,105
Regulatory liabilities	12,885	8,316
Operating lease liabilities	27,722	27,218
Dividends declared	29,960	132
Transmission interconnection arrangement liabilities	42,666	39,564
Other current liabilities	101,017	99,149
Total current liabilities	673,043	664,213
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	3,620,041	3,519,580
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	772,263	764,850
Regulatory liabilities	845,701	841,393
Asset retirement obligations	236,877	234,146
Accrued pension liability and postretirement benefit cost	15,772	19,057
Operating lease liabilities	47,369	55,993
Other deferred credits	335,291	333,195
Total deferred credits and liabilities	2,253,273	2,248,634
Total liabilities	6,546,357	6,432,427
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
PNM common stockholder’s equity:
Common stock (no par value; 40,000,000 shares authorized; issued and outstanding 39,117,799 shares)	1,425,574	1,429,257
Accumulated other comprehensive income (loss), net of income taxes	(76,580)	(71,936)
Retained earnings	766,538	810,203
Total PNM common stockholder’s equity	2,115,532	2,167,524
Non-controlling interest in Valencia	54,268	55,405
Total equity	2,169,800	2,222,929
Total liabilities and stockholders' equity	8,727,686	8,666,885
PNM
Current Assets:
Cash and cash equivalents	2,985	19
Accounts receivable, net of allowance for credit losses of $6,392 and $7,265	87,329	98,151
Unbilled revenues	31,424	44,759
Other receivables	16,871	16,538
Affiliate receivables	8,895	8,837
Materials, supplies, and fuel stock	62,578	57,942
Regulatory assets	13,749	8,721
Prepaid assets	18,639	30,266
Other current assets	995	1,456
Total current assets	243,465	266,689
Other Property and Investments:
Investment securities	431,097	463,126
Other investments	38	129
Non-utility property, net	10,426	10,717
Total other property and investments	441,561	473,972
Utility Plant:
Plant in service, held for future use, and to be abandoned	6,655,734	6,602,015
Less accumulated depreciation and amortization	2,268,349	2,235,068
Net plant in service and plant held for future use	4,387,385	4,366,947
Construction work in progress	184,282	182,520
Nuclear fuel, net of accumulated amortization of $47,131 and $41,181	99,381	98,937
Net utility plant	4,671,048	4,648,404
Deferred Charges and Other Assets:
Regulatory assets	426,177	428,981
Goodwill	51,632	51,632
Operating lease right-of-use assets, net of accumulated amortization	69,022	73,903
Other deferred charges	137,183	116,552
Total deferred charges and other assets	684,014	671,068
Assets	6,040,088	6,060,133
Current Liabilities:
Short-term debt	4,700	7,400
Current installments of long-term debt	179,419	179,339
Accounts payable	74,299	107,795
Affiliate payables	10,768	15,203
Customer deposits	5,364	5,095
Accrued interest and taxes	52,011	37,137
Regulatory liabilities	12,885	8,316
Operating lease liabilities	25,826	25,278
Dividends declared	132	132
Transmission interconnection arrangement liabilities	40,666	39,564
Other current liabilities	78,269	70,643
Total current liabilities	484,339	495,902
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	1,702,214	1,701,771
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	634,592	630,682
Regulatory liabilities	651,495	653,830
Asset retirement obligations	236,098	233,383
Accrued pension liability and postretirement benefit cost	15,448	18,718
Operating lease liabilities	44,377	52,552
Other deferred credits	246,202	246,502
Total deferred credits and liabilities	1,828,212	1,835,667
Total liabilities	4,014,765	4,033,340
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
PNM common stockholder’s equity:
Common stock (no par value; 40,000,000 shares authorized; issued and outstanding 39,117,799 shares)	1,547,918	1,547,918
Accumulated other comprehensive income (loss), net of income taxes	(76,580)	(71,936)
Retained earnings	488,188	483,877
Total PNM common stockholder’s equity	1,959,526	1,959,859
Non-controlling interest in Valencia	54,268	55,405
Total equity	2,013,794	2,015,264
Total liabilities and stockholders' equity	$ 6,040,088	$ 6,060,133

Condensed Consolidated Balanc_4

Condensed Consolidated Balance Sheets - PNM (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Allowance for uncollectible accounts	$ 6,392	$ 7,265
Accumulated depreciation, nuclear fuel	$ 47,131	$ 41,181
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	$ 6,392	$ 7,265
Accumulated depreciation, nuclear fuel	$ 47,131	$ 41,181
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

Condensed Consolidated State_10

Condensed Consolidated Statements of Changes in Equity - PNM - USD ($) $ in Thousands	Total	Total PNMR Common Stockholders’ Equity	Common Stock	AOCI	Retained Earnings	Non- controlling Interest in Valencia	PNM	PNMTotal PNMR Common Stockholders’ Equity	PNMCommon Stock	PNMAOCI	PNMRetained Earnings	PNMNon- controlling Interest in Valencia
Beginning balance at Dec. 31, 2020	$ 2,108,474	$ 2,049,465	$ 1,429,941	$ (79,183)	$ 698,707	$ 59,009	$ 1,863,752	$ 1,804,743	$ 1,494,918	$ (78,511)	$ 388,336	$ 59,009
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Earnings	21,205	17,711			17,711	3,494	22,162	18,668			18,668	3,494
Total other comprehensive income (loss)	(3,159)	(3,159)		(3,159)			(3,623)	(3,623)		(3,623)
Dividends declared on preferred stock							(132)	(132)			(132)
Valencia’s transactions with its owner	(5,243)					(5,243)	(5,243)					(5,243)
Ending balance at Mar. 31, 2021	2,088,226	2,030,966	1,425,133	(82,342)	688,175	57,260	1,876,916	1,819,656	1,494,918	(82,134)	406,872	57,260
Beginning balance at Dec. 31, 2021	2,222,929	2,167,524	1,429,257	(71,936)	810,203	55,405	2,015,264	1,959,859	1,547,918	(71,936)	483,877	55,405
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Earnings	19,218	16,123			16,123	3,095	7,538	4,443			4,443	3,095
Total other comprehensive income (loss)	(4,644)	(4,644)		(4,644)			(4,644)	(4,644)		(4,644)
Dividends declared on preferred stock							(132)	(132)			(132)
Valencia’s transactions with its owner	(4,232)					(4,232)	(4,232)					(4,232)
Ending balance at Mar. 31, 2022	$ 2,169,800	$ 2,115,532	$ 1,425,574	$ (76,580)	$ 766,538	$ 54,268	$ 2,013,794	$ 1,959,526	$ 1,547,918	$ (76,580)	$ 488,188	$ 54,268

Condensed Consolidated State_11

Condensed Consolidated Statements of Earnings - TNMP - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Cost of Revenue [Abstract]
Contracts with customers	$ 384,493	$ 346,585
Alternative revenue programs	(5,505)	(909)
Total electric operating revenues	444,118	364,707
Operating Expenses:
Administrative and general	55,861	59,465
Depreciation and amortization	75,764	69,874
Transmission and distribution costs	18,466	17,317
Taxes other than income taxes	23,979	22,593
Total operating expenses	376,050	321,541
Operating income	68,068	43,166
Other Income and Deductions:
Interest income	4,292	3,559
Other income	4,330	4,252
Other (deductions)	(2,241)	(3,290)
Net other income and deductions	(20,192)	5,489
Interest Charges	26,220	25,884
Earnings before Income Taxes	21,656	22,771
Income Taxes	2,438	1,566
Texas-New Mexico Power Company
Cost of Revenue [Abstract]
Contracts with customers	108,849	95,379
Alternative revenue programs	(3,440)	(1,885)
Total electric operating revenues	105,409	93,494
Operating Expenses:
Cost of energy	29,600	26,510
Administrative and general	12,013	12,230
Depreciation and amortization	23,642	22,190
Transmission and distribution costs	6,855	6,658
Taxes other than income taxes	9,057	8,881
Total operating expenses	81,167	76,469
Operating income	24,242	17,025
Other Income and Deductions:
Interest income	1,182	0
Other income	1,052	1,386
Other (deductions)	(115)	(324)
Net other income and deductions	2,119	1,062
Interest Charges	9,150	8,475
Earnings before Income Taxes	17,211	9,612
Income Taxes	2,151	877
Net Earnings Attributable to PNM	$ 15,060	$ 8,735

Condensed Consolidated State_12

Condensed Consolidated Statements of Cash Flows - TNMP - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net earnings	$ 19,218	$ 21,205
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	84,672	78,857
Deferred income tax expense	2,009	1,447
Allowance for equity funds used during construction	(2,668)	(2,621)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	21,169	17,205
Materials, supplies, and fuel stock	(5,183)	4,305
Other current assets	13,079	(18,978)
Other assets	(12,215)	6,561
Accounts payable	(15,905)	(9,647)
Accrued interest and taxes	909	76
Other current liabilities	(6,458)	(4,369)
Other liabilities	(12,263)	(14,050)
Net cash flows from operating activities	116,610	86,477
Cash Flows From Investing Activities:
Utility plant additions	(209,884)	(172,235)
Net cash flows used in investing activities	(211,864)	(174,455)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings, net	23,300	165,500
Transmission interconnection and security deposit arrangements	18,569	5,460
Debt issuance costs and other, net	(431)	(292)
Net cash flows from financing activities	98,539	47,571
Change in Cash, Restricted Cash, and Equivalents	3,285	(40,407)
Cash, Restricted Cash, and Equivalents at Beginning of Period	1,104	47,928
Cash, Restricted Cash, and Equivalents at End of Period	4,389	7,521
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	21,682	23,317
Income taxes (refunded), net	(346)	0
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	38,918	49,092
Texas-New Mexico Power Company
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net earnings	15,060	8,735
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	23,856	22,428
Deferred income tax expense	(345)	(1,471)
Allowance for equity funds used during construction	(374)	(477)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(1,297)	(286)
Materials, supplies, and fuel stock	(547)	(36)
Other current assets	1,670	1,231
Other assets	(1,329)	1,322
Accounts payable	(3,848)	(3,182)
Accrued interest and taxes	(12,485)	(9,911)
Other current liabilities	(599)	(373)
Other liabilities	(802)	(1,310)
Net cash flows from operating activities	18,960	16,670
Cash Flows From Investing Activities:
Utility plant additions	(100,556)	(76,149)
Net cash flows used in investing activities	(100,556)	(76,149)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings, net	74,600	43,100
Short-term borrowings – affiliate, net	700	0
Transmission interconnection and security deposit arrangements	6,400	1,650
Debt issuance costs and other, net	(104)	(71)
Net cash flows from financing activities	81,596	44,679
Change in Cash, Restricted Cash, and Equivalents	0	(14,800)
Cash, Restricted Cash, and Equivalents at Beginning of Period	0	14,800
Cash, Restricted Cash, and Equivalents at End of Period	0	0
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	10,020	9,229
Income taxes (refunded), net	(346)	0
Supplemental schedule of noncash investing activities:
Decrease in accrued plant additions	$ 1,237	$ 13,465

Condensed Consolidated Balanc_5

Condensed Consolidated Balance Sheets - TNMP - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 4,389	$ 1,104
Accounts receivable	116,015	123,292
Unbilled revenues	42,153	57,736
Other receivables	19,414	18,784
Materials, supplies, and fuel stock	70,244	65,061
Regulatory assets	18,597	14,785
Other current assets	1,082	1,635
Total current assets	301,145	324,600
Other Property and Investments:
Other investments	174	265
Non-utility property, net	24,420	25,439
Total other property and investments	545,035	577,988
Utility Plant:
Plant in service, held for future use, and to be abandoned	9,448,704	9,357,849
Less accumulated depreciation and amortization	3,003,558	2,952,743
Net plant in service and plant held for future use	6,445,146	6,405,106
Construction work in progress	313,901	248,856
Net utility plant	6,858,428	6,752,899
Deferred Charges and Other Assets:
Regulatory assets	511,639	514,258
Goodwill	278,297	278,297
Operating lease right-of-use assets, net of accumulated amortization	74,126	79,511
Other deferred charges	159,016	139,332
Total deferred charges and other assets	1,023,078	1,011,398
Assets	8,727,686	8,666,885
Current Liabilities:
Short-term debt	86,000	62,700
Accounts payable	117,772	172,595
Accrued interest and taxes	70,238	70,105
Operating lease liabilities	27,722	27,218
Transmission interconnection arrangement liabilities	42,666	39,564
Other current liabilities	101,017	99,149
Total current liabilities	673,043	664,213
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	3,620,041	3,519,580
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	772,263	764,850
Regulatory liabilities	845,701	841,393
Asset retirement obligations	236,877	234,146
Accrued pension liability and postretirement benefit cost	15,772	19,057
Operating lease liabilities	47,369	55,993
Other deferred credits	335,291	333,195
Total deferred credits and liabilities	2,253,273	2,248,634
Total liabilities	6,546,357	6,432,427
Commitments and Contingencies (Note 11)
PNM common stockholder’s equity:
Common stock ($10 par value; 12,000,000 shares authorized; issued and outstanding 6,358 shares)	1,425,574	1,429,257
Retained earnings	766,538	810,203
Total PNM common stockholder’s equity	2,115,532	2,167,524
Total liabilities and stockholders' equity	8,727,686	8,666,885
Texas-New Mexico Power Company
Current Assets:
Cash and cash equivalents	0	0
Accounts receivable	28,686	25,141
Unbilled revenues	10,729	12,977
Other receivables	4,439	4,108
Materials, supplies, and fuel stock	7,666	7,119
Regulatory assets	4,848	6,064
Other current assets	1,301	1,989
Total current assets	57,669	57,398
Other Property and Investments:
Other investments	136	136
Non-utility property, net	12,793	13,499
Total other property and investments	12,929	13,635
Utility Plant:
Plant in service, held for future use, and to be abandoned	2,505,711	2,475,859
Less accumulated depreciation and amortization	574,255	563,004
Net plant in service and plant held for future use	1,931,456	1,912,855
Construction work in progress	122,220	53,401
Net utility plant	2,053,676	1,966,256
Deferred Charges and Other Assets:
Regulatory assets	85,462	85,277
Goodwill	226,665	226,665
Operating lease right-of-use assets, net of accumulated amortization	4,782	5,264
Other deferred charges	8,898	10,277
Total deferred charges and other assets	325,807	327,483
Assets	2,450,081	2,364,772
Current Liabilities:
Short-term debt	75,000	400
Short-term debt - affiliate	700	0
Accounts payable	38,004	43,089
Affiliate payables	3,574	6,568
Accrued interest and taxes	27,520	40,005
Operating lease liabilities	1,853	1,882
Transmission interconnection arrangement liabilities	2,000	0
Other current liabilities	6,639	4,968
Total current liabilities	155,290	96,912
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	918,025	918,050
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	159,291	157,248
Regulatory liabilities	194,206	187,563
Asset retirement obligations	779	763
Accrued pension liability and postretirement benefit cost	324	339
Operating lease liabilities	2,713	3,155
Other deferred credits	62,836	59,185
Total deferred credits and liabilities	420,149	408,253
Total liabilities	1,493,464	1,423,215
Commitments and Contingencies (Note 11)
PNM 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	737,166
Retained earnings	219,387	204,327
Total PNM common stockholder’s equity	956,617	941,557
Total liabilities and stockholders' equity	$ 2,450,081	$ 2,364,772

Condensed Consolidated Balanc_6

Condensed Consolidated Balance Sheets - TNMP (Parenthetical) - $ / shares	Mar. 31, 2022	Dec. 31, 2021
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
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

Condensed Consolidated State_13

Condensed Consolidated Statements of Changes in Common Stockholder's Equity - TNMP - USD ($) $ in Thousands	Total	Texas-New Mexico Power Company	Texas-New Mexico Power CompanyCommon Stock	Texas-New Mexico Power CompanyPaid-in Capital	Texas-New Mexico Power CompanyRetained Earnings
Beginning balance TNMP at Dec. 31, 2020		$ 825,678	$ 64	$ 685,166	$ 140,448
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings		8,735			8,735
Ending balance TNMP at Mar. 31, 2021		834,413	64	685,166	149,183
Beginning balance TNMP at Dec. 31, 2021	$ 2,167,524	941,557	64	737,166	204,327
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings		15,060			15,060
Ending balance TNMP at Mar. 31, 2022	$ 2,115,532	$ 956,617	$ 64	$ 737,166	$ 219,387

Significant Accounting Policies

Significant Accounting Policies and Responsibility for Financial Statements	3 Months Ended
	Mar. 31, 2022
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 March 31, 2022 and December 31, 2021, and the consolidated results of operations, comprehensive income, and cash flows for the three months ended March 31, 2022 and 2021. 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 2021 Condensed Consolidated Financial Statements and Notes thereto have been reclassified to conform to the 2022 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 2021 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. The Board declared dividends on common stock of $0.3475 per share in February 2022 and $0.3275 per share in March 2021, which are reflected as "Dividends Declared per Common Share" on the PNMR Condensed Consolidated Statements of Earnings. PNMR did not make any cash equity contributions to PNM or TNMP in the three months ended March 31, 2022 and 2021. Neither PNM nor TNMP declared or paid any cash dividends to PNMR in the three months ended March 31, 2022 and 2021.

Segment Information

Segment Information	3 Months Ended
	Mar. 31, 2022
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 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 PNMR Consolidated (In thousands) Three Months Ended March 31, 2022 Electric operating revenues $ 338,709 $ 105,409 $ — $ 444,118 Cost of energy 138,814 29,600 — 168,414 Utility margin 199,895 75,809 — 275,704 Other operating expenses 109,089 27,925 (5,142) 131,872 Depreciation and amortization 45,790 23,642 6,332 75,764 Operating income (loss) 45,016 24,242 (1,190) 68,068 Interest income 3,133 1,182 (23) 4,292 Other income (deductions) (25,216) 937 (205) (24,484) Interest charges (14,572) (9,150) (2,498) (26,220) Segment earnings (loss) before income taxes 8,361 17,211 (3,916) 21,656 Income taxes (benefit) 823 2,151 (536) 2,438 Segment earnings (loss) 7,538 15,060 (3,380) 19,218 Valencia non-controlling interest (3,095) — — (3,095) Subsidiary preferred stock dividends (132) — — (132) Segment earnings (loss) attributable to PNMR $ 4,311 $ 15,060 $ (3,380) $ 15,991 At March 31, 2022: Total Assets $ 6,040,088 $ 2,450,081 $ 237,517 $ 8,727,686 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 PNM TNMP Corporate PNMR Consolidated (In thousands) Three Months Ended March 31, 2021 Electric operating revenues $ 271,213 $ 93,494 $ — $ 364,707 Cost of energy 88,886 26,510 — 115,396 Utility margin 182,327 66,984 — 249,311 Other operating expenses 107,328 27,769 1,174 136,271 Depreciation and amortization 41,949 22,190 5,735 69,874 Operating income (loss) 33,050 17,025 (6,909) 43,166 Interest income 3,595 — (36) 3,559 Other income (deductions) 1,244 1,062 (376) 1,930 Interest charges (12,893) (8,475) (4,516) (25,884) Segment earnings (loss) before income taxes 24,996 9,612 (11,837) 22,771 Income taxes (benefit) 2,834 877 (2,145) 1,566 Segment earnings (loss) 22,162 8,735 (9,692) 21,205 Valencia non-controlling interest (3,494) — — (3,494) Subsidiary preferred stock dividends (132) — — (132) Segment earnings (loss) attributable to PNMR $ 18,536 $ 8,735 $ (9,692) $ 17,579 At March 31, 2021: Total Assets $ 5,561,146 $ 2,163,250 $ 218,913 $ 7,943,309 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.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	3 Months Ended
	Mar. 31, 2022
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	Accumulated Other Comprehensive Income (Loss) Information regarding accumulated other comprehensive income (loss) for the three months ended March 31, 2022 and 2021 is as follows: Accumulated Other Comprehensive Income (Loss) PNM Corporate and Other PNMR Consolidated Unrealized Pension Fair Value Total Total (In thousands) Balance at December 31, 2021 $ 11,715 $ (83,651) $ (71,936) $ — $ (71,936) Amounts reclassified from AOCI (pre-tax) (1,477) 1,776 299 — 299 Income tax impact of amounts reclassified 375 (451) (76) — (76) Other OCI changes (pre-tax) (6,524) — (6,524) — (6,524) Income tax impact of other OCI changes 1,657 — 1,657 — 1,657 Net after-tax change (5,969) 1,325 (4,644) — (4,644) Balance at March 31, 2022 $ 5,746 $ (82,326) $ (76,580) $ — $ (76,580) Balance at December 31, 2020 $ 20,403 $ (98,914) $ (78,511) $ (672) $ (79,183) Amounts reclassified from AOCI (pre-tax) (3,618) 2,087 (1,531) (624) (2,155) Income tax impact of amounts reclassified 919 (530) 389 158 547 Other OCI changes (pre-tax) (3,326) — (3,326) 1,247 (2,079) Income tax impact of other OCI changes 845 — 845 (317) 528 Net after-tax change (5,180) 1,557 (3,623) 464 (3,159) Balance at March 31, 2021 $ 15,223 $ (97,357) $ (82,134) $ (208) $ (82,342) 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.

Earnings Per Share

Earnings Per Share	3 Months Ended
	Mar. 31, 2022
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. Information regarding the computation of earnings per share is as follows: Three Months Ended March 31, 2022 2021 (In thousands, except per share amounts) Net Earnings Attributable to PNMR $ 15,991 $ 17,579 Average Number of Common Shares: Outstanding during period 85,835 85,835 Vested awards of restricted stock 256 196 Average Shares – Basic 86,091 86,031 Dilutive Effect of Common Stock Equivalents: Restricted stock 80 24 Average Shares – Diluted 86,171 86,055 Net Earnings Per Share of Common Stock: Basic $ 0.19 $ 0.20 Diluted $ 0.19 $ 0.20

Electric Operating Revenues

Electric Operating Revenues	3 Months Ended
	Mar. 31, 2022
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 2021 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 $(0.9) million and $1.6 million in the three months ended March 31, 2022 and 2021. 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 months ended March 31, 2022 and 2021, there were no 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 deferred bad debt expense (credit losses) from defaulting REPs to a regulatory asset which totaled $0.8 million at both March 31, 2022 and December 31, 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 March 31, 2022 (In thousands) Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 112,574 $ 39,368 $ 151,942 Commercial 88,004 33,103 121,107 Industrial 23,132 8,390 31,522 Public authority 4,426 1,526 5,952 Economy energy service 8,940 — 8,940 Transmission 34,526 25,529 60,055 Miscellaneous 4,042 933 4,975 Total revenues from contracts with customers 275,644 108,849 384,493 Alternative revenue programs (2,065) (3,440) (5,505) Other electric operating revenues (1) 65,130 — 65,130 Total Electric Operating Revenues $ 338,709 $ 105,409 $ 444,118 (1) Increase in 2022 is primarily the result of participation in the EIM beginning in April 2021. PNM TNMP PNMR Consolidated Three Months Ended March 31, 2021 (In thousands) Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 114,669 $ 35,094 $ 149,763 Commercial 81,934 29,429 111,363 Industrial 18,900 7,293 26,193 Public authority 4,587 1,482 6,069 Economy energy service 10,581 — 10,581 Transmission 17,503 21,121 38,624 Miscellaneous 3,032 960 3,992 Total revenues from contracts with customers 251,206 95,379 346,585 Alternative revenue programs 976 (1,885) (909) Other electric operating revenues 19,031 — 19,031 Total Electric Operating Revenues $ 271,213 $ 93,494 $ 364,707 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 $77.7 million at March 31, 2022 and $86.8 million at December 31, 2021 resulting from contracts with customers. All of TNMP’s accounts receivable results from contracts with customers. Contract assets are an entity’s right to consideration in exchange for goods or services that the entity has transferred to a customer when that right is conditioned on something other than the passage of time (for example, the entity’s future performance). Upon the completion of the Western Spirit Line, PNM entered into a TSA with Pattern Wind under an incremental tariff rate approved by FERC. The terms of the agreement provide for a financing component that benefits the customer. As such, the revenue that PNM recognizes will be in excess of the consideration received at the beginning of the service term resulting in a contract asset. The balance of the contract asset as of March 31, 2022 is $3.4 million and $0.6 million as of December 31, 2021. This contract asset is presented in Other deferred charges on the Condensed Consolidated Balance Sheet. 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.

Variable Interest Entities

Variable Interest Entities	3 Months Ended
	Mar. 31, 2022
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 2021 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 months ended March 31, 2022 and 2021, PNM paid $4.8 million and $4.9 million for fixed charges and $0.1 million and $0.2 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 March 31, 2022 2021 (In thousands) Operating revenues $ 4,932 $ 5,127 Operating expenses 1,837 1,633 Earnings attributable to non-controlling interest $ 3,095 $ 3,494 Financial Position March 31, December 31, 2022 2021 (In thousands) Current assets $ 3,206 $ 3,042 Net property, plant, and equipment 52,198 52,908 Total assets 55,404 55,950 Current liabilities 1,136 545 Owners’ equity – non-controlling interest $ 54,268 $ 55,405 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.

Fair Value of Derivative and Ot

Fair Value of Derivative and Other Financial Instruments	3 Months Ended
	Mar. 31, 2022
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 2021 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 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 were passed through to customers under the FPPAC. 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 three months ended March 31, 2022 and the year ended December 31, 2021, 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 March 31, December 31, (In thousands) Other current assets $ 183 $ 684 Other deferred charges — — 183 684 Other current liabilities (3,852) (2,275) Other deferred credits — — (3,852) (2,275) Net $ (3,669) $ (1,591) 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 $0.2 million at March 31, 2022 and $0.5 million at December 31, 2021, resulting 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 zero and $0.2 million in current assets and $3.7 million and $1.8 million of current liabilities related to this plan at March 31, 2022 and December 31, 2021. At March 31, 2022 and December 31, 2021, PNM had no amounts recognized for the legal right to reclaim cash collateral. However, at both March 31, 2022 and December 31, 2021, 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 March 31, 2022 and December 31, 2021, obligations to return cash collateral were $0.9 million, which is included in other current liabilities 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 months ended March 31, 2022 and 2021 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 122,400 MWh at both March 31, 2022 and December 31, 2021. PNM had no open gas commodity volume positions at March 31, 2022 or December 31, 2021. 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 March 31, 2022 and December 31, 2021, 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 March 31, 2022 and December 31, 2021, the fair value of investment securities included $364.1 million and $394.5 million for the NDT and $67.0 million and $68.6 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 March 31, 2022 and December 31, 2021, 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 March 31, 2022 2021 (In thousands) Equity securities: Net gains from equity securities sold $ 5,006 $ 2,022 Net (losses) from equity securities still held (22,035) (3,166) Total net (losses) on equity securities (17,029) (1,144) Available-for-sale debt securities: Net gains (losses) on debt securities (9,544) 2,112 Net gains (losses) on investment securities $ (26,573) $ 968 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 $(8.9) million and $1.1 million for the three months ended March 31, 2022 and 2021. Three Months Ended March 31, 2022 2021 (In thousands) Proceeds from sales $ 125,246 $ 123,596 Gross realized gains $ 10,178 $ 8,692 Gross realized (losses) $ (5,840) $ (3,443) At March 31, 2022, the available-for-sale debt securities held by PNM, had the following final maturities: Fair Value (In thousands) Within 1 year $ 32,919 After 1 year through 5 years 70,710 After 5 years through 10 years 87,507 After 10 years through 15 years 16,377 After 15 years through 20 years 12,815 After 20 years 34,865 $ 255,193 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 March 31, 2022 and December 31, 2021. 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) March 31, 2022 Cash and cash equivalents $ 13,935 $ 13,935 $ — Equity securities: Corporate stocks, common 84,240 84,240 — Corporate stocks, preferred 8,253 3,349 4,904 Mutual funds and other 69,476 69,476 — Available-for-sale debt securities: U.S. government 56,695 53,720 2,975 $ 283 International government 13,004 — 13,004 832 Municipals 43,828 — 43,828 227 Corporate and other 141,666 — 141,666 6,398 $ 431,097 $ 224,720 $ 206,377 $ 7,740 Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Unrealized Gains (In thousands) December 31, 2021 Cash and cash equivalents $ 7,895 $ 7,895 $ — Equity securities: Corporate stocks, common 97,626 97,626 — Corporate stocks, preferred 9,114 3,775 5,339 Mutual funds and other 75,285 75,241 44 Available-for-sale debt securities: U.S. government 43,128 13,204 29,924 $ 214 International government 16,001 — 16,001 1,508 Municipals 47,050 — 47,050 1,807 Corporate and other 167,027 — 167,027 12,212 $ 463,126 $ 197,741 $ 265,385 $ 15,741 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 March 31, 2022 (In thousands) PNMR $ 3,799,460 $ 3,708,586 PNM $ 1,881,633 $ 1,785,939 TNMP $ 918,025 $ 922,647 December 31, 2021 PNMR $ 3,698,919 $ 3,915,010 PNM $ 1,881,110 $ 1,975,987 TNMP $ 918,050 $ 1,039,023 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.

Stock-Based Compensation

Stock-Based Compensation	3 Months Ended
	Mar. 31, 2022
Share-based Payment Arrangement [Abstract]
Stock-Based Compensation	Stock-Based Compensation PNMR has various stock-based compensation programs, which provide restricted stock awards 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. Certain restricted stock awards are subject to achieving performance or market targets. Other awards of restricted stock are only subject to time vesting requirements. Restricted stock expected to be awarded under the PEP for performance periods ending after 2023, no longer have market targets. Additional information concerning stock-based compensation under the PEP is contained in Note 12 of the Notes to Consolidated Financial Statements in the 2021 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 March 31, 2022, PNMR had unrecognized expense related to stock awards of $6.8 million, which is expected to be recognized over an average of 2.0 years. 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 were 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: Three Months Ended March 31, Restricted Shares and Performance Based Shares 2022 2021 Expected quarterly dividends per share $ 0.3475 $ 0.3275 Risk-free interest rate 1.46 % 0.32 % Market-Based Shares Dividend yield — % 2.76 % Expected volatility — % 33.69 % Risk-free interest rate — % 0.29 % The following table summarizes activity in restricted stock awards, including performance-based and market-based shares for the three months ended March 31, 2022: Restricted Stock Shares Weighted- Outstanding at December 31, 2021 167,270 $ 43.71 Granted 171,919 40.66 Released (152,740) 41.80 Forfeited (682) 40.27 Outstanding at March 31, 2022 185,767 $ 45.64 PNMR’s current stock-based compensation program provides for performance targets through 2024 and market targets through 2023. Included, as granted and released, in the table above are 92,343 previously awarded shares that were earned for the 2019 - 2021 performance measurement period and ratified by the Board in February 2022 (based upon achieving targets at below "maximum" levels). Excluded from the table above are 142,047, 152,414, and 173,051 shares for the three-year performance periods ending in 2022, 2023 and 2024 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: Three Months Ended March 31, Restricted Stock 2022 2021 Weighted-average grant date fair value $ 40.66 $ 43.68 Total fair value of restricted shares that vested (in thousands) $ 6,906 $ 8,967

Financing

Financing	3 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
Financing	FinancingThe 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 2021 Annual Reports on Form 10-K. Financing Activities On April 27, 2022, TNMP entered into an agreement (the "TNMP 2022 Bond Purchase Agreement") with institutional investors for the sale of $160.0 million aggregate principal amount of two series of TNMP first mortgage bonds (the "TNMP 2022 Bonds") offered in private placement transactions. TNMP will issue the first series of $65.0 million of the TNMP 2022 Bonds on May 12, 2022, at a 4.13% interest rate, due May 12, 2052 and the second series of $95.0 million of the TNMP 2022 Bonds will be issued on or before July 28, 2022, at a 3.81% interest rate, due July 28, 2032. The proceeds will be used to repay borrowings under the TNMP Revolving Credit Facility and for other corporate purposes. The TNMP 2022 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the supplemental indenture governing the TNMP 2022 Bonds. The terms of the supplemental indenture governing the TNMP 2022 Bonds include the customary covenants discussed above. In the event of a change of control, TNMP will be required to offer to prepay the TNMP 2022 Bonds at par. However, the definition of change of control in the supplemental indenture governing the TNMP 2022 Bonds will not be triggered by the close of the Merger. TNMP has the right to redeem any or all of the TNMP 2022 Bonds prior to their maturity, subject to payment of a customary make-whole premium. On 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, N.A., as administrative agent. In 2021, PNMR drew $900.0 million to repay and terminate existing indebtedness as discussed in Note 7 of the Notes to Consolidated Financial Statements in the 2021 Annual Reports on Form 10-K. On January 24, 2022, PNMR drew the remaining $100.0 million available. On March 9, 2018, PNMR issued $300.0 million aggregate principal amount of 3.25% SUNs (the “PNMR 2018 SUNs”), which matured on March 9, 2021. On December 22, 2020, PNMR entered into the $300.0 million PNMR 2020 Delayed-Draw Term Loan with a January 2022 maturity 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. The PNMR 2020 Delayed-Draw Term Loan was prepaid without penalty in May 2021 with proceeds from the PNMR 2021 Delayed-Draw Term Loan. At March 31, 2022, variable interest rates were 1.29% on the PNMR 2021 Delayed-Draw Term Loan that matures in May 2023 and 1.28% on the PNM 2021 Term Loan that matures in December 2022. 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 has a financing capacity of $75.0 million secured by $75.0 million aggregate principal amount of TNMP first mortgage bonds. On March 11, 2022, the TNMP Revolving Credit Facility was amended to extend the maturity to September 23, 2024, replace the LIBOR benchmark with SOFR, include two one-year extension options, subject to approval by a majority of the lenders, and incorporate an accordion feature that would allow TNMP to increase the size of the revolver to $100.0 million subject to certain conditions. PNMR Development had a $40.0 million revolving credit facility that was scheduled to expire on January 31, 2022. On May 18, 2021, the PNMR Development Revolving Credit Facility was terminated. Variable interest rates under the PNMR and PNM 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: March 31, December 31, Short-term Debt 2022 2021 (In thousands) PNM Revolving Credit Facility $ 4,700 $ 7,400 TNMP Revolving Credit Facility 75,000 400 PNMR Revolving Credit Facility 6,300 54,900 $ 86,000 $ 62,700 At March 31, 2022, the weighted average interest rates were 1.70% for the PNM Revolving Credit Facility, 1.25% for the TNMP Revolving Credit Facility, and 1.95% for the PNMR Revolving Credit Facility. There were no borrowings outstanding under the PNM 2017 New Mexico Revolving Credit Facility at March 31, 2022. In addition to the above borrowings, PNMR, PNM, and TNMP had letters of credit outstanding of $3.4 million, zero, and zero at March 31, 2022 that reduce the available capacity under their respective revolving credit facilities. In addition, PNMR had $30.3 million of letters of credit outstanding under the WFB LOC Facility. The above table excludes intercompany debt. As of March 31, 2022 and December 31, 2021, neither PNM nor PNMR Development had any intercompany borrowings from PNMR. TNMP had $0.7 million and zero in intercompany borrowings from PNMR at March 31, 2022 and December 31, 2021. PNMR had $6.3 million and $6.4 million in intercompany borrowings from PNMR Development at March 31, 2022 and December 31, 2021. 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 April 21, 2022, PNMR, PNM, and TNMP had availability of $265.5 million, $400.0 million, and zero under their respective revolving credit facilities, including reductions of availability due to outstanding letters of credit. PNM had $40.0 million of availability under the PNM 2017 New Mexico Credit Facility. Total availability at April 21, 2022, on a consolidated basis, was $705.5 million for PNMR. As of April 21, 2022, PNM and PNMR Development had no borrowings from PNMR under their intercompany loan agreements. However, TNMP had $30.2 million in intercompany borrowings from PNMR. PNMR had $6.3 million in intercompany borrowings from PNMR Development. At April 21, 2022, PNMR, PNM, and TNMP had invested cash of $0.9 million, $8.7 million, and zero. The Company’s debt arrangements have various maturities and expiration dates. PNM has $104.5 million of PCRBs that must be refinanced or repriced in June 2022 and the PNM 2021 $75.0 million Term Loan matures in December 2022. Additional information on debt maturities is contained in Note 7 of the Notes to Consolidated Financial Statements in the 2021 Annual Reports on Form 10-K.

Pension and Other Postretiremen

Pension and Other Postretirement Benefit Plans	3 Months Ended
	Mar. 31, 2022
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 2021 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 March 31, Pension Plan OPEB Plan Executive Retirement Program 2022 2021 2022 2021 2022 2021 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ 2 $ 6 $ — $ — Interest cost 4,214 4,036 479 477 90 90 Expected return on plan assets (7,141) (7,133) (1,088) (1,042) — — Amortization of net loss 3,949 4,541 — — 82 100 Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 1,022 $ 1,444 $ (607) $ (559) $ 172 $ 190 PNM did not make any contributions to its pension plan trust in the three months ended March 31, 2022 and 2021 and does not anticipate making any contributions to the pension plan in 2022 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 three months ended March 31, 2022 and 2021, 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 $0.9 million for both the three months ended March 31, 2022 and 2021. These payments are expected to total $3.2 million in 2022 and $11.9 million for 2023-2026. Disbursements under the executive retirement program, which are funded by PNM and considered to be contributions to the plan, were $0.4 million in both the three months ended March 31, 2022 and 2021 and are expected to total $1.3 million during 2022 and $4.7 million for 2023-2026. TNMP Plans The following table presents the components of the TNMP Plans’ net periodic benefit cost: Three Months Ended March 31, Pension Plan OPEB Plan Executive Retirement Program 2022 2021 2022 2021 2022 2021 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ 9 $ 11 $ — $ — Interest cost 430 435 77 77 3 4 Expected return on plan assets (618) (795) (104) (102) — — Amortization of net (gain) loss 233 312 (130) (80) — 9 Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 45 $ (48) $ (148) $ (94) $ 3 $ 13 TNMP did not make any contributions to its pension plan trust in the three months ended March 31, 2022 and 2021 and does not anticipate making any contributions to the pension plan in 2022 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 months ended March 31, 2022 and 2021 and does not expect to make contributions to the OPEB trust during

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2022
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 2021 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 March 31, 2022 and December 31, 2021, PNM had a liability for interim storage costs of $12.4 million and $13.0 million, which is included in other deferred credits. PVNGS has sufficient capacity at its on-site Independent Spent Fuel Storage Installation (“ISFSI”) to store all of the nuclear fuel that will be irradiated during the initial operating license period, which ends in December 2027. Additionally, PVNGS has sufficient capacity at its on-site ISFSI to store a portion of the fuel that will be irradiated during the period of extended operation, which ends in November 2047. If uncertainties regarding the U.S. government’s obligation to accept and store spent fuel are not favorably resolved, APS will evaluate alternative storage solutions that may obviate the need to expand the ISFSI to accommodate all of the fuel that will be irradiated during the period of extended operation. The Energy Transition Act 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 CO 2 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. 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 previously released 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, which deadline NMED was unable to meet. NMED is currently preparing its SIP for the second compliance period and has notified PNM that it will not be required to submit a regional haze four-factor analysis for SJGS since PNM will retire its share of SJGS in 2022. On April 7, 2022, EPA announced its intent to make findings by August 31, 2022 of the states that have failed to submit regional haze implementation plans for the second planning period and directed states to file their plans by August 15, 2022 to avoid inclusion in that finding. Despite that announcement, on April 13, 2022, four environmental groups sued EPA in the U.S. District Court for the Northern District of California seeking to compel EPA to issue a finding that 34 states failed to submit regional haze SIPs for the second planning period. NMED’s current timeline indicates the proposed SIP will be submitted between July 2022 and January 2023. Carbon Dioxide Emissions On August 3, 2015, EPA established standards to limit CO 2 emissions from power plants, including (1) Carbon Pollution Standards for new, modified, and reconstructed power plants; and (2) the Clean Power Plan for existing power plants. 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 in separate cases. 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 rules were 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 of an individual facility. 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. The ACE Rule was also challenged, and on January 19, 2021, the DC Circuit issued an opinion in American Lung Association and American Public Health Association v. EPA, et al., finding that EPA misinterpreted the CAA when it determined that the language of Section 111 unambiguously barred consideration of emissions reduction options that were not applied at the source. As a result, the court vacated the ACE Rule and remanded the record back to the EPA for further consideration consistent with the court's opinion. While the DC Circuit rejected 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. EPA has commenced the rulemaking process under section 111 to establish new emission guidelines for CO 2 emissions from existing power plants. The agency indicates that it plans to publish the draft rule in the summer of 2022 with a final rule in summer of 2023. Four petitions for writ of certiorari were filed in the US Supreme Court seeking review of the DC Circuit’s January opinion vacating the ACE Rule and the repeal of the Clean Power Plan. 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. On October 29, 2021, the US Supreme Court granted the four petitions for writs of certiorari. Oral arguments in the US Supreme Court were held on February 28, 2022. A decision is expected by the end of June 2022. 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 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, SO 2 , 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 NO 2 is the constituent of greatest concern and is the indicator for the primary NAAQS. EPA concluded that the current 1-hour and annual primary NO 2 standards are requisite to protect public health with an adequate margin of safety. The rule became effective on May 18, 2018. PNM maintains compliance with the current NOx NAAQS standards. SO 2 Standard – On February 25, 2019, EPA announced its final decision to retain, without changes, the primary health-based NAAQS for SO 2 . Specifically, EPA will retain the current 1-hour standard for SO 2 , which is 75 parts per billion, based on the 3-year average of the 99th percentile of daily maximum 1-hour SO 2 concentrations. PNM maintains compliance with the current SO 2 NAAQS standards. 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 SO 2 Primary NAAQS. This is EPA’s fourth and final set of actions to designate areas of the U.S. for the 2010 SO 2 NAAQS. All areas of New Mexico have been designated attainment/unclassifiable through four rounds of designations by 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. In response to lawsuits brought by states and environmental groups, on October 29, 2021, EPA filed a motion in the DC Circuit indicating it will reconsider the 2020 ozone NAAQS standard. EPA expects to complete this review by the end of 2023. 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 Non-attainment Area SIP. This includes a transportation conformity demonstration, a 2017 baseline emissions inventory and emissions statement, and an amendment to the state's Non-attainment 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, and 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 Non-attainment 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. With respect to EPA's reconsideration of the 2020 decision to retain the 2015 ozone standards, 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 PM 2.5 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. PNM maintains compliance with the current PM NAAQS standards and cannot predict the impacts of the outcome of future rulemaking. Cooling Water Intake Structures In 2014, EPA issued a rule establishing national standards for certain cooling water intake structures at existing power plants and other facilities under the Clean Water Act to protect fish and other aquatic organisms by minimizing impingement mortality (the capture of aquatic wildlife on intake structures or against screens) and entrainment mortality (the capture of fish or shellfish in water flow entering and passing through intake structures). To minimize impingement mortality, the rule provides operators of facilities, such as 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 planned retirement of SJGS in 2022. On May 23, 2018, several environmental groups sued EPA Region IX in the U.S. 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 ELG, 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. On March 21, 2022, EPA provided notice in the Federal Register of a proposed settlement agreement with the environmental groups. Under the proposed settlement, the parties would seek to stay the associated case for at least 15 months during which a third-party consultant would spend 12 months sampling discharges from Four Corners and EPA would spend three months completing an analysis. Comments on the proposed settlement were due by April 20, 2022. PNM cannot predict whether the parties will ultimately sign the settlement agreement or whether the analysis to be conducted under the settlement agreement will result in changes to the NPDES permit that 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 ELG establishing technology-based wastewater discharge limitations for fossil fuel-fired electric power plants. EPA signed the final Steam Electric ELG 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 ELG 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 postpo

Regulatory and Rate Matters

Regulatory and Rate Matters	3 Months Ended
	Mar. 31, 2022
Regulated Operations [Abstract]
Regulatory and Rate Matters	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 2021 Annual Reports on Form 10-K. PNMR Merger Regulatory Proceedings 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. Among other conditions, consummation of the Merger is subject to receipt of all required regulatory approvals. Five federal agencies and the PUCT have completed their reviews and approved the Merger, leaving the NMPRC as the only remaining approval necessary for the Merger. The original application before the NMPRC was filed in November 2020. For additional information on the Merger regulatory proceedings see Note 17. PNM Renewable Energy Portfolio Standard As discussed in Note 11, the ETA, enacted on June 14, 2019, amends the REA including removal of diversity requirements and certain customer caps and exemptions relating to the application of the RPS under the REA. The REA provides for streamlined proceedings for approval of utilities’ renewable energy procurement plans, assures that utilities recover costs incurred consistent with approved procurement plans, and requires the NMPRC to establish a 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 the renewable energy rider billed on a KWh basis. Included in PNM’s approved procurement plans are the following renewable energy resources: • 158 MW of PNM-owned solar-PV facilities • A PPA through 2044 for the output of New Mexico Wind, having a current aggregate capacity of 200 MW, and a PPA through 2035 for the output of Red Mesa Wind, having an aggregate capacity of 102 MW • A PPA through 2040 for 140 MW of output from La Joya Wind II • A PPA through 2042 for the output of the Lightning Dock Geothermal facility with a current capacity of 11 MW • Solar distributed generation, aggregating 211.8 MW at March 31, 2022, owned by customers or third parties from whom PNM purchases any net excess output and RECs The NMPRC has authorized PNM to recover certain renewable procurement costs through a rate rider billed on a per KWh basis. In its 2022 renewable energy procurement plan, which became effective on January 1, 2022, PNM proposed to collect $66.9 million for the year. PNM recorded revenues from the rider of $14.5 million and $15.9 million in the three months ended March 31, 2022 and 2021. 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 2021. The NMPRC currently has an open inquiry docket into the continued use of renewable riders by New Mexico utilities. PNM is unable to predict the outcome of the NMPRC's inquiry. 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. 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 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, 2022, PNM filed an Advice Notice which reconciles the actual 2021 energy efficiency profit incentive collections with the profit incentive authorized by the NMPRC resulting in an additional $0.3 million incentive to be collected through the energy efficiency rider during the remainder of 2022. The additional incentive was authorized for 2021 because annual energy savings for the year exceeded 94 GWh. PNM will begin collecting the incentive effective May 31, 2022, unless suspended by the NMPRC. 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, as modified in rebuttal testimony, would increase if PNM is able to achieve savings greater than 94 GWh in a year. 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. 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, PNM would collect the difference from customers if the revenue per customer from the NM 2015 Rate Case exceeds the actual revenue recovered, or return the difference to customers if the actual revenue per customer recovered 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 supported PNM's petition, but recommended 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 opposed 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. On January 14, 2022, the hearing examiner issued a recommended decision recommending the NMPRC find that the EUEA does not mandate the NMPRC to authorize or approve a full decoupling mechanism, defining full decoupling as limited to energy efficiency and load management measures and programs. The recommended decision also states that a utility may request approval of a rate adjustment mechanism to remove regulatory disincentives to energy efficiency and load management measures and programs through a stand-alone petition, as part of the utility’s triennial energy efficiency application or a general rate case and that PNM is not otherwise precluded from petitioning for a rate adjustment mechanism prior to its next general rate case. Finally, the recommended decision stated that the EUEA does not permit the NMPRC to reduce a utility’s ROE based on approval of a disincentive removal mechanism founded on removing regulatory disincentives to energy efficiency and load management measures and programs. The recommended decision does not specifically prohibit a downward adjustment to a utility’s capital structure, based on approval of a disincentive removal mechanism. On April 27, 2022, the NMPRC issued an order adopting the recommended decision in its entirety. 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 was 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 was filed on November 12, 2021. The recommendation found that PNM has met the requirements of the IRP rule, but not the requirements of the NM 2016 Rate Case. On April 6, 2022, the NMPRC issued an order requiring PNM to update its 2020 IRP and to identify material events, including the SJGS extension and replacement resource delays, and the related impact to its plan. On April 27, 2022, PNM responded to the NMPRC order, as required. PNM cannot predict the outcome of this matter. 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 energy transition bonds. PNM's application proposed several replacement resource scenarios. The SJGS Abandonment Application also included a request to issue 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. The NMPRC indicated that PNM's July 1, 2019 filing is responsive to the January 30, 2019 order. 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 examiners 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 a rate rider to collect non-bypassable customer charges for repayment of the bonds and be subject to bi-annual adjustments (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, 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 asserted that the NMPRC improperly applied the ETA and that the ETA violates the New Mexico Constitution. 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. On January 10, 2022, the NM Supreme Court issued its decision rejecting CFRE’s and NEE’s constitutional challenges to the ETA and affirmed the NMPRC final order. 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 $36.9 million and $36.0 million is reflected in other current liabilities and as a corresponding deferred regulatory asset on PNMR's and PNM's Condensed Consolidated Balance Sheets at December 31, 2021. In the three months ended March 31, 2022, PNM paid $8.9 million for obligations to fund severances and other costs of WSJ LLC employees. PNM revised its estimates in the first quarter reflecting other current liabilities of $27.7 million and $26.8 million and deferred regulatory assets of $36.8 million and $35.9 million on PNMR's and PNM's Condensed Consolidated Balance Sheets at March 31, 2022. These estimates may continue to be adjusted in future periods as the Company refines its expectations. 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 that 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 not in evidence that had 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 the 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. Throughout 2021 and continuing into 2022, PNM provided notices of delays and status updates to the NMPRC for the approved SJGS replacement resource projects. All four project developers have notified PNM that completion of the projects will be delayed and no longer available for the 2022 summer peak and some may also not be available for the 2023 summer peak. The delays in the SJGS replacement resources, coupled with the abandonment of SJGS Units 1 and 4 present a risk that PNM will not have sufficient operational resources to meet the 2022 summer peak demand and reliably serve its customers unless PNM is able to place additional generation resources in service. In the second half of 2021, PNM entered into three agreements to purchase power from third parties to minimize potential impacts to customers; 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. After considering these additional contracts, PNM projected a system reserve margin ranging from 0.9% to (3.4%) during the 2022 summer peak. As a result, on February 17, 2022, PNM filed a Notice and Request for Modification to or Variance from Abandonment Date for SJGS Unit 4 with the NMPRC. The filing provided notice that PNM had obtained agreement from the SJGS owners and WSJ LLC to extend operation of SJGS Unit 4 until September 30, 2022. SJGS Unit 4 will provide 327 MW of capacity and improve PNM’s projected system reserve margin to a range from 17.4% to 9.8%. On February 23, 2022, the NMPRC issued an order finding that PNM did not require NMPRC approval to extend operation of SJGS Unit 4 for an additional three-month period. The NMPRC’s order states that issues regarding the prudence or reasonableness of the decisions made, actions taken by PNM, and recoverability of costs related to the continued operation of SJGS Unit 4, including fuel costs collected through PNM’s FPPAC, shall be subject to review in a future proceeding. On February 25, 2022, the amended San Juan Project Participation Agreement was filed with FERC. On March 18, 2022, PNM filed its Compliance Notice updating its January 26, 2022 Compliance Notice indicating that 65 MW of SJGS Unit 4 owned as a deregulated merchant resource will be available to PNM retail operations on a system contingent basis, which increases PNM's projected system reserve margin to a range from 20.7% to 12.5% during the 2022 summer peak. On March 24, 2022, FERC accepted the amended SJGS participation agreement. Given the non-normal geological condition impeding longwall progress in the San Juan Mine, PNM does not know whether reduced levels of coal inventory may continue to impact full load operations through the remainder of the CSA and the projected system reserve margin for the 2022 summer peak. See Note 11. On February 28, 2022, WRA and CCAE filed a Joint Motion for Order to Show Cause and Enforce Financing Order and Supporting Brief, which requests that the NMPRC order PNM to show cause why its rates should not be reduced at the time SJGS is abandoned, and to otherwise enforce the NMPRC’s April 1, 2020 final order. On March 14, 2022, PNM filed its response to the Joint Motion to Show Cause refuting the movants' claims that the ETA and April 1, 2020 Financing Order require energy transition bonds be issued at the time of abandonment and that rates be reduced upon abandonment as not being legally supportable. The movants filed joint replies on March 24, 2022. In response, on March 30, 2022, the NMPRC issued an Order appointing hearing examiners to conduct a hearing, if necessary, and to issue a recommended decision to address the issues raised by the motion. The Order also states that the hearing examiners should endeavor to issue a recommended decision with sufficient time for consideration of exceptions and for the NMPRC to be able to take action prior to June 30, 2022. The hearing examiners issued a procedural order which required PNM to file testimony on April 20, 2022 and scheduled a hearing to begin on May 23, 2022. PNM cannot predict the outcome of this matter. Additional information concerning the SJGS Abandonment Application is contained in Note 17 of the Notes to Consolidated Financial Statements in the 2021 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 will 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. 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 deferred charges on the Condensed Consolidated Balance Sheet as of March 31, 2022 and December 31, 2021. On January 8, 2021, PNM filed the Four Corners Abandonment Application, which sought NMPRC approval to exit PNM’s share of Four Corners as of December 31, 2024, and issuance of approximately $300 million of 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, an estimated $7.3 million in upfront financing costs, and an 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 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 November 12, 2021, the hearing examiner issued a recommended decision recommending approval of the Four Corners Abandonment Application and the corresponding request for issuance of securitized financing. On December 15, 2021, the NMPRC issued a final order rejecting the hearing examiners recommended decision and denying approval of the Four Corners Abandonment Application and the corresponding request for issuance of securitized financing. In its order, the NMPRC concluded that PNM needed to conduct a review of the actual replacement resource portfolio and determined that the record was insufficient to determine the prudence of PNM’s investments in Four Corners. On December 22, 2021, PNM filed a Notice of Appeal with the NM Supreme Court of the NMPRC decision to deny the application. On January 21, 2022, PNM filed a statement of issues outlining the arguments for appeal asserting, among other things, that the NMPRC misinterpreted and improperly applied the ETA in concluding that the NMPRC needed to review the actual replacement resource portfolio before authorizing abandonment and that the NMPRC improperly deferred the issue of prudence with respect to certain of PNM’s investments in Four Corners, where other parties were given the opportunity to present evidence and failed to demonstrate PNM was imprudent in its decisions. On March 24, 2022, PNM filed its Brief in Chief and answer briefs are due from the NMPRC on May 9, 2022. GAAP requires a loss be recognized when it is probable that a loss has been incurred and the amount of loss can be reasonably estimated. As of March 31, 2022, PNM evaluated the NMPRC order in the Four Corners Abandonment Application and determined it was reasonably possible that PNM would be successful in recovery of its undepreciated investment in a future proceeding. Therefore, no loss has been recorded. 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 the Leased Interest with new resources. 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. PNM's application sought a six-month regulatory time frame. On April 21, 2021, the NMPRC issued an order assigning a hearing examiner and st

Lease Commitments

Lease Commitments	3 Months Ended
	Mar. 31, 2022
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 2021 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 March 31, 2022, amounts due to the lessors under the circumstances described above would be up to $145.0 million, payable on July 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 2022 payment for the amount due under the Navajo Nation right-of-way lease was $7.8 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 March 31, 2022 and December 31, 2021, the unamortized balance of these rights-of-ways was $52.6 million and $53.4 million. PNM recognized amortization expense associated with these agreements of $1.0 million and $0.9 million in the three months ended March 31, 2022 and 2021. 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 March 31, 2022, residual value guarantees on fleet vehicle and equipment leases are $0.9 million, $1.4 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: March 31, 2022 December 31, 2021 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating leases: Operating lease assets, net of amortization $ 69,022 $ 4,782 $ 74,126 $ 73,903 $ 5,264 $ 79,511 Current portion of operating lease liabilities 25,826 1,853 27,722 25,278 1,882 27,218 Long-term portion of operating lease liabilities 44,377 2,713 47,369 52,552 3,155 55,993 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: March 31, 2022 December 31, 2021 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Financing leases: Non-utility property $ 15,613 $ 16,232 $ 32,188 $ 15,171 $ 16,181 $ 31,695 Accumulated depreciation (5,282) (5,679) (11,171) (4,550) (4,923) (9,660) Non-utility property, net 10,331 10,553 21,017 10,621 11,258 22,035 Other current liabilities 2,818 2,975 5,881 2,731 2,994 5,813 Other deferred credits 7,373 7,586 15,008 7,732 8,273 16,075 Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities as of March 31, 2022 is presented below: PNM TNMP PNMR Consolidated Weighted average remaining lease term (years): Operating leases 6.23 2.75 6.02 Financing leases 4.10 3.93 4.00 Weighted average discount rate: Operating leases 4.03 % 4.00 % 4.02 % Financing leases 2.62 % 2.71 % 2.66 % Information for the components of lease expense is as follows: Three Months Ended March 31, 2022 PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: $ 6,683 $ 528 $ 7,237 Amounts capitalized (185) (469) (654) Total operating lease expense 6,498 59 6,583 Financing lease cost: Amortization of right-of-use assets 732 757 1,511 Interest on lease liabilities 68 73 141 Amounts capitalized (497) (717) (1,213) Total financing lease expense 303 113 439 Variable lease expense 106 — 106 Short-term lease expense (1) 1,132 — 1,169 Total lease expense for the period $ 8,039 $ 172 $ 8,297 (1) Includes expense of $1.1 million for the three months ended March 31, 2022 for rental of temporary cooling towers associated with the SJGS Unit 1 outage. These amounts are offset with insurance reimbursements of $1.1 million for the three months ended March 31, 2022. For additional information on the SJGS Unit 1 outage see Note 12. Three Months Ended March 31, 2021 PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: $ 6,735 $ 653 $ 7,429 Amounts capitalized (226) (559) (785) Total operating lease expense 6,509 94 6,644 Financing lease cost: Amortization of right-of-use assets 532 613 1,167 Interest on lease liabilities 62 76 139 Amounts capitalized (368) (625) (993) Total financing lease expense 226 64 313 Variable lease expense 63 — 63 Short-term lease expense 124 2 132 Total lease expense for the period $ 6,922 $ 160 $ 7,152 Supplemental cash flow information related to the Company’s leases is as follows: Three Months Ended Three Months Ended March 31, 2022 March 31, 2021 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 $ 9,244 $ 49 $ 9,318 $ 9,246 $ 97 $ 9,401 Operating cash flows from financing leases 22 8 31 21 8 30 Finance cash flows from financing leases 260 104 386 186 71 278 Non-cash information related to right-of-use assets obtained in exchange for lease obligations: Operating leases $ 1,079 $ — $ 1,079 $ — $ 317 $ 317 Financing leases 441 51 492 758 387 1,164 Capitalized lease costs are reflected as investing activities on the Company’s Condensed Consolidated Statements of Cash Flows for the three months ended March 31, 2022 and 2021. Future expected lease payments are shown below: As of March 31, 2022 PNM TNMP PNMR Consolidated Financing Operating Financing Operating Financing Operating (In thousands) Remainder of 2022 $ 2,293 $ 16,918 $ 2,435 $ 1,496 $ 4,797 $ 18,630 2023 2,952 17,778 3,028 1,546 6,035 19,558 2024 2,267 7,953 2,557 943 4,838 8,958 2025 1,450 6,992 1,648 770 3,100 7,802 2026 1,048 6,928 844 76 1,892 7,042 Later years 801 22,132 613 — 1,414 22,315 Total minimum lease payments 10,811 78,701 11,125 4,831 22,076 84,305 Less: Imputed interest 620 8,498 564 265 1,187 9,214 Lease liabilities as of March 31, 2022 $ 10,191 $ 70,203 $ 10,561 $ 4,566 $ 20,889 $ 75,091 The above table includes $11.6 million, $13.7 million, and $25.3 million for PNM, TNMP, and PNMR at March 31, 2022 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.
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 2021 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 March 31, 2022, amounts due to the lessors under the circumstances described above would be up to $145.0 million, payable on July 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 2022 payment for the amount due under the Navajo Nation right-of-way lease was $7.8 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 March 31, 2022 and December 31, 2021, the unamortized balance of these rights-of-ways was $52.6 million and $53.4 million. PNM recognized amortization expense associated with these agreements of $1.0 million and $0.9 million in the three months ended March 31, 2022 and 2021. 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 March 31, 2022, residual value guarantees on fleet vehicle and equipment leases are $0.9 million, $1.4 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: March 31, 2022 December 31, 2021 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating leases: Operating lease assets, net of amortization $ 69,022 $ 4,782 $ 74,126 $ 73,903 $ 5,264 $ 79,511 Current portion of operating lease liabilities 25,826 1,853 27,722 25,278 1,882 27,218 Long-term portion of operating lease liabilities 44,377 2,713 47,369 52,552 3,155 55,993 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: March 31, 2022 December 31, 2021 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Financing leases: Non-utility property $ 15,613 $ 16,232 $ 32,188 $ 15,171 $ 16,181 $ 31,695 Accumulated depreciation (5,282) (5,679) (11,171) (4,550) (4,923) (9,660) Non-utility property, net 10,331 10,553 21,017 10,621 11,258 22,035 Other current liabilities 2,818 2,975 5,881 2,731 2,994 5,813 Other deferred credits 7,373 7,586 15,008 7,732 8,273 16,075 Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities as of March 31, 2022 is presented below: PNM TNMP PNMR Consolidated Weighted average remaining lease term (years): Operating leases 6.23 2.75 6.02 Financing leases 4.10 3.93 4.00 Weighted average discount rate: Operating leases 4.03 % 4.00 % 4.02 % Financing leases 2.62 % 2.71 % 2.66 % Information for the components of lease expense is as follows: Three Months Ended March 31, 2022 PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: $ 6,683 $ 528 $ 7,237 Amounts capitalized (185) (469) (654) Total operating lease expense 6,498 59 6,583 Financing lease cost: Amortization of right-of-use assets 732 757 1,511 Interest on lease liabilities 68 73 141 Amounts capitalized (497) (717) (1,213) Total financing lease expense 303 113 439 Variable lease expense 106 — 106 Short-term lease expense (1) 1,132 — 1,169 Total lease expense for the period $ 8,039 $ 172 $ 8,297 (1) Includes expense of $1.1 million for the three months ended March 31, 2022 for rental of temporary cooling towers associated with the SJGS Unit 1 outage. These amounts are offset with insurance reimbursements of $1.1 million for the three months ended March 31, 2022. For additional information on the SJGS Unit 1 outage see Note 12. Three Months Ended March 31, 2021 PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: $ 6,735 $ 653 $ 7,429 Amounts capitalized (226) (559) (785) Total operating lease expense 6,509 94 6,644 Financing lease cost: Amortization of right-of-use assets 532 613 1,167 Interest on lease liabilities 62 76 139 Amounts capitalized (368) (625) (993) Total financing lease expense 226 64 313 Variable lease expense 63 — 63 Short-term lease expense 124 2 132 Total lease expense for the period $ 6,922 $ 160 $ 7,152 Supplemental cash flow information related to the Company’s leases is as follows: Three Months Ended Three Months Ended March 31, 2022 March 31, 2021 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 $ 9,244 $ 49 $ 9,318 $ 9,246 $ 97 $ 9,401 Operating cash flows from financing leases 22 8 31 21 8 30 Finance cash flows from financing leases 260 104 386 186 71 278 Non-cash information related to right-of-use assets obtained in exchange for lease obligations: Operating leases $ 1,079 $ — $ 1,079 $ — $ 317 $ 317 Financing leases 441 51 492 758 387 1,164 Capitalized lease costs are reflected as investing activities on the Company’s Condensed Consolidated Statements of Cash Flows for the three months ended March 31, 2022 and 2021. Future expected lease payments are shown below: As of March 31, 2022 PNM TNMP PNMR Consolidated Financing Operating Financing Operating Financing Operating (In thousands) Remainder of 2022 $ 2,293 $ 16,918 $ 2,435 $ 1,496 $ 4,797 $ 18,630 2023 2,952 17,778 3,028 1,546 6,035 19,558 2024 2,267 7,953 2,557 943 4,838 8,958 2025 1,450 6,992 1,648 770 3,100 7,802 2026 1,048 6,928 844 76 1,892 7,042 Later years 801 22,132 613 — 1,414 22,315 Total minimum lease payments 10,811 78,701 11,125 4,831 22,076 84,305 Less: Imputed interest 620 8,498 564 265 1,187 9,214 Lease liabilities as of March 31, 2022 $ 10,191 $ 70,203 $ 10,561 $ 4,566 $ 20,889 $ 75,091 The above table includes $11.6 million, $13.7 million, and $25.3 million for PNM, TNMP, and PNMR at March 31, 2022 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.

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2022
Income Tax Disclosure [Abstract]
Income Taxes	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 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 2020, the IRS finalized regulations interpreting Tax Act amendments to depreciation provisions of the IRC that allowed 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 2021 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 and paid $3.5 million of payroll taxes in December 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 excess deferred income taxes of $23.6 million, $14.4 million, and $9.2 million in 2022. 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 2021 Annual Reports on Form 10-K.

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2022
Related Party Transactions [Abstract]
Related Party Transactions	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. The table below summarizes the nature and amount of related party transactions of PNMR, PNM, TNMP, and NMRD: Three Months Ended March 31, 2022 2021 (In thousands) Services billings: PNMR to PNM $ 27,693 $ 26,225 PNMR to TNMP 10,304 10,365 PNM to TNMP 93 118 TNMP to PNMR 35 12 PNMR to NMRD 64 55 Renewable energy purchases: PNM from NMRD 2,621 2,585 Interconnection and facility study billings: PNM to NMRD — — PNM to PNMR — — NMRD to PNM — 1,276 Interest billings: PNMR to PNM 7 — PNM to PNMR 23 36 PNMR to TNMP 45 — Income tax sharing payments: PNMR to PNM — — TNMP to PNMR — —

Equity Method Investment

Equity Method Investment	3 Months Ended
	Mar. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investment	Equity Method Investment As discussed in Note 1 of the Company's 2021 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 March 31, 2022, 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 three months ended March 31, 2022 and 2021, neither PNMR Development nor AEP OnSite Partners made any cash contributions to NMRD for its construction activities. In February 2021, NMRD paid both PNMR Development and AEP OnSite Partners a dividend of $3.0 million. PNMR Development's cumulative equity in earnings of NMRD as of March 31, 2021 was $2.4 million and is presented as cash flows from operating activities on the Condensed Consolidated Statement of Cash Flows for the three months ended March 31, 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 March 31, 2022 2021 (In thousands) Operating revenues $ 2,796 $ 2,750 Operating expenses 2,404 2,522 Net earnings $ 392 $ 228 Financial Position March 31, December 31, 2022 2021 (In thousands) Current assets $ 5,827 $ 10,729 Net property, plant, and equipment 164,733 166,495 Non-current assets 9,653 2,289 Total assets 180,213 179,513 Current liabilities 1,148 824 Non-current liabilities 377 373 Owners’ equity $ 178,688 $ 178,316

Merger

Merger	3 Months Ended
	Mar. 31, 2022
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 PNMR common stock 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. The Merger Agreement provided that it may be terminated by each of PNMR and Avangrid under certain circumstances, including if the Effective Time shall not have occurred by the January 20, 2022 End Date; however, either PNMR or Avangrid could extend the End Date to April 20, 2022 if all conditions to closing have been satisfied other than the obtaining of all required regulatory approvals. As discussed below, on December 8, 2021, the NMPRC issued an order rejecting the stipulation agreement relating to the Merger. In light of the NMPRC ruling, on January 3, 2022, PNMR, Avangrid and Merger Sub entered into an Amendment to the Merger Agreement pursuant to which PNMR and Avangrid agreed to extend the End Date to April 20, 2023. The Merger is subject to certain regulatory approvals, including from the NMPRC. The Joint Applicants (PNMR and Avangrid) to the NMPRC application and a number of intervening parties had entered into an amended stipulation and agreement in the Joint Application for approval of Merger pending before the NMPRC. An evidentiary hearing was held in August 2021. On November 1, 2021, a Certification of Stipulation was issued by the hearing examiner, which recommended against approval of the amended stipulation. On December 8, 2021, the NMPRC issued an order adopting the Certification of Stipulation, rejecting the amended stipulation reached by the parties. On January 3, 2022, PNMR and Avangrid filed a notice of appeal with the NM Supreme Court. On February 2, 2022, PNMR and Avangrid filed a statement of issues outlining the argument for appeal. On April 7, 2022, PNMR and Avangrid filed their Brief in Chief with the NM Supreme Court. Answer briefs are due from the NMPRC on June 13, 2022, and response briefs are due July 6, 2022. With respect to other regulatory proceedings related to the Merger, in 2021 PNMR received clearances for the Merger from the FTC under the HSR Act, CFIUS, the FCC, FERC, the PUCT, and the NRC. As a result of the delay in closing of the Merger due to the need to obtain NMPRC approval, PNMR and Avangrid were required to make a new filing under the HSR Act and request extensions of approvals previously received from the FCC and NRC. On February 9, 2022, the request for extension was filed with the NRC. On February 24, 2022, the requests for a 180-day extension were granted by the FCC. PNMR and Avangrid expect to make a new filing under the HSR Act later in 2022. No additional approvals are required from CFIUS, FERC or the PUCT. 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 is in full effect and related filings have been made with the NMPRC. The Merger Agreement provides for certain customary termination rights. 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) and in either case prior to PNMR's shareholder having approved the Merger), 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).

Significant Accounting Polici_2

Significant Accounting Policies and Responsibility for Financial Statements (Policies)	3 Months Ended
	Mar. 31, 2022
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.

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2022
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 PNMR Consolidated (In thousands) Three Months Ended March 31, 2022 Electric operating revenues $ 338,709 $ 105,409 $ — $ 444,118 Cost of energy 138,814 29,600 — 168,414 Utility margin 199,895 75,809 — 275,704 Other operating expenses 109,089 27,925 (5,142) 131,872 Depreciation and amortization 45,790 23,642 6,332 75,764 Operating income (loss) 45,016 24,242 (1,190) 68,068 Interest income 3,133 1,182 (23) 4,292 Other income (deductions) (25,216) 937 (205) (24,484) Interest charges (14,572) (9,150) (2,498) (26,220) Segment earnings (loss) before income taxes 8,361 17,211 (3,916) 21,656 Income taxes (benefit) 823 2,151 (536) 2,438 Segment earnings (loss) 7,538 15,060 (3,380) 19,218 Valencia non-controlling interest (3,095) — — (3,095) Subsidiary preferred stock dividends (132) — — (132) Segment earnings (loss) attributable to PNMR $ 4,311 $ 15,060 $ (3,380) $ 15,991 At March 31, 2022: Total Assets $ 6,040,088 $ 2,450,081 $ 237,517 $ 8,727,686 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 PNM TNMP Corporate PNMR Consolidated (In thousands) Three Months Ended March 31, 2021 Electric operating revenues $ 271,213 $ 93,494 $ — $ 364,707 Cost of energy 88,886 26,510 — 115,396 Utility margin 182,327 66,984 — 249,311 Other operating expenses 107,328 27,769 1,174 136,271 Depreciation and amortization 41,949 22,190 5,735 69,874 Operating income (loss) 33,050 17,025 (6,909) 43,166 Interest income 3,595 — (36) 3,559 Other income (deductions) 1,244 1,062 (376) 1,930 Interest charges (12,893) (8,475) (4,516) (25,884) Segment earnings (loss) before income taxes 24,996 9,612 (11,837) 22,771 Income taxes (benefit) 2,834 877 (2,145) 1,566 Segment earnings (loss) 22,162 8,735 (9,692) 21,205 Valencia non-controlling interest (3,494) — — (3,494) Subsidiary preferred stock dividends (132) — — (132) Segment earnings (loss) attributable to PNMR $ 18,536 $ 8,735 $ (9,692) $ 17,579 At March 31, 2021: Total Assets $ 5,561,146 $ 2,163,250 $ 218,913 $ 7,943,309 Goodwill $ 51,632 $ 226,665 $ — $ 278,297

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	3 Months Ended
	Mar. 31, 2022
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	Information regarding accumulated other comprehensive income (loss) for the three months ended March 31, 2022 and 2021 is as follows: Accumulated Other Comprehensive Income (Loss) PNM Corporate and Other PNMR Consolidated Unrealized Pension Fair Value Total Total (In thousands) Balance at December 31, 2021 $ 11,715 $ (83,651) $ (71,936) $ — $ (71,936) Amounts reclassified from AOCI (pre-tax) (1,477) 1,776 299 — 299 Income tax impact of amounts reclassified 375 (451) (76) — (76) Other OCI changes (pre-tax) (6,524) — (6,524) — (6,524) Income tax impact of other OCI changes 1,657 — 1,657 — 1,657 Net after-tax change (5,969) 1,325 (4,644) — (4,644) Balance at March 31, 2022 $ 5,746 $ (82,326) $ (76,580) $ — $ (76,580) Balance at December 31, 2020 $ 20,403 $ (98,914) $ (78,511) $ (672) $ (79,183) Amounts reclassified from AOCI (pre-tax) (3,618) 2,087 (1,531) (624) (2,155) Income tax impact of amounts reclassified 919 (530) 389 158 547 Other OCI changes (pre-tax) (3,326) — (3,326) 1,247 (2,079) Income tax impact of other OCI changes 845 — 845 (317) 528 Net after-tax change (5,180) 1,557 (3,623) 464 (3,159) Balance at March 31, 2021 $ 15,223 $ (97,357) $ (82,134) $ (208) $ (82,342)

Earnings Per Share (Tables)

Earnings Per Share (Tables)	3 Months Ended
	Mar. 31, 2022
Earnings Per Share [Abstract]
Computation of Earnings Per Share	Information regarding the computation of earnings per share is as follows: Three Months Ended March 31, 2022 2021 (In thousands, except per share amounts) Net Earnings Attributable to PNMR $ 15,991 $ 17,579 Average Number of Common Shares: Outstanding during period 85,835 85,835 Vested awards of restricted stock 256 196 Average Shares – Basic 86,091 86,031 Dilutive Effect of Common Stock Equivalents: Restricted stock 80 24 Average Shares – Diluted 86,171 86,055 Net Earnings Per Share of Common Stock: Basic $ 0.19 $ 0.20 Diluted $ 0.19 $ 0.20

Electric Operating Revenues (Ta

Electric Operating Revenues (Tables)	3 Months Ended
	Mar. 31, 2022
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 March 31, 2022 (In thousands) Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 112,574 $ 39,368 $ 151,942 Commercial 88,004 33,103 121,107 Industrial 23,132 8,390 31,522 Public authority 4,426 1,526 5,952 Economy energy service 8,940 — 8,940 Transmission 34,526 25,529 60,055 Miscellaneous 4,042 933 4,975 Total revenues from contracts with customers 275,644 108,849 384,493 Alternative revenue programs (2,065) (3,440) (5,505) Other electric operating revenues (1) 65,130 — 65,130 Total Electric Operating Revenues $ 338,709 $ 105,409 $ 444,118 (1) Increase in 2022 is primarily the result of participation in the EIM beginning in April 2021. PNM TNMP PNMR Consolidated Three Months Ended March 31, 2021 (In thousands) Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 114,669 $ 35,094 $ 149,763 Commercial 81,934 29,429 111,363 Industrial 18,900 7,293 26,193 Public authority 4,587 1,482 6,069 Economy energy service 10,581 — 10,581 Transmission 17,503 21,121 38,624 Miscellaneous 3,032 960 3,992 Total revenues from contracts with customers 251,206 95,379 346,585 Alternative revenue programs 976 (1,885) (909) Other electric operating revenues 19,031 — 19,031 Total Electric Operating Revenues $ 271,213 $ 93,494 $ 364,707

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	3 Months Ended
	Mar. 31, 2022
Variable Interest Entities [Abstract]
Summarized Financial Information	Summarized financial information for Valencia is as follows: Results of Operations Three Months Ended March 31, 2022 2021 (In thousands) Operating revenues $ 4,932 $ 5,127 Operating expenses 1,837 1,633 Earnings attributable to non-controlling interest $ 3,095 $ 3,494 Financial Position March 31, December 31, 2022 2021 (In thousands) Current assets $ 3,206 $ 3,042 Net property, plant, and equipment 52,198 52,908 Total assets 55,404 55,950 Current liabilities 1,136 545 Owners’ equity – non-controlling interest $ 54,268 $ 55,405

Fair Value of Derivative and _2

Fair Value of Derivative and Other Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2022
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 March 31, December 31, (In thousands) Other current assets $ 183 $ 684 Other deferred charges — — 183 684 Other current liabilities (3,852) (2,275) Other deferred credits — — (3,852) (2,275) Net $ (3,669) $ (1,591)
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 March 31, 2022 2021 (In thousands) Equity securities: Net gains from equity securities sold $ 5,006 $ 2,022 Net (losses) from equity securities still held (22,035) (3,166) Total net (losses) on equity securities (17,029) (1,144) Available-for-sale debt securities: Net gains (losses) on debt securities (9,544) 2,112 Net gains (losses) on investment securities $ (26,573) $ 968 Three Months Ended March 31, 2022 2021 (In thousands) Proceeds from sales $ 125,246 $ 123,596 Gross realized gains $ 10,178 $ 8,692 Gross realized (losses) $ (5,840) $ (3,443)
Investments Classified by Contractual Maturity Date	At March 31, 2022, the available-for-sale debt securities held by PNM, had the following final maturities: Fair Value (In thousands) Within 1 year $ 32,919 After 1 year through 5 years 70,710 After 5 years through 10 years 87,507 After 10 years through 15 years 16,377 After 15 years through 20 years 12,815 After 20 years 34,865 $ 255,193
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) March 31, 2022 Cash and cash equivalents $ 13,935 $ 13,935 $ — Equity securities: Corporate stocks, common 84,240 84,240 — Corporate stocks, preferred 8,253 3,349 4,904 Mutual funds and other 69,476 69,476 — Available-for-sale debt securities: U.S. government 56,695 53,720 2,975 $ 283 International government 13,004 — 13,004 832 Municipals 43,828 — 43,828 227 Corporate and other 141,666 — 141,666 6,398 $ 431,097 $ 224,720 $ 206,377 $ 7,740 Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Unrealized Gains (In thousands) December 31, 2021 Cash and cash equivalents $ 7,895 $ 7,895 $ — Equity securities: Corporate stocks, common 97,626 97,626 — Corporate stocks, preferred 9,114 3,775 5,339 Mutual funds and other 75,285 75,241 44 Available-for-sale debt securities: U.S. government 43,128 13,204 29,924 $ 214 International government 16,001 — 16,001 1,508 Municipals 47,050 — 47,050 1,807 Corporate and other 167,027 — 167,027 12,212 $ 463,126 $ 197,741 $ 265,385 $ 15,741
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 March 31, 2022 (In thousands) PNMR $ 3,799,460 $ 3,708,586 PNM $ 1,881,633 $ 1,785,939 TNMP $ 918,025 $ 922,647 December 31, 2021 PNMR $ 3,698,919 $ 3,915,010 PNM $ 1,881,110 $ 1,975,987 TNMP $ 918,050 $ 1,039,023

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2022
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: Three Months Ended March 31, Restricted Shares and Performance Based Shares 2022 2021 Expected quarterly dividends per share $ 0.3475 $ 0.3275 Risk-free interest rate 1.46 % 0.32 % Market-Based Shares Dividend yield — % 2.76 % Expected volatility — % 33.69 % Risk-free interest rate — % 0.29 % The following table summarizes activity in restricted stock awards, including performance-based and market-based shares for the three months ended March 31, 2022: Restricted Stock Shares Weighted- Outstanding at December 31, 2021 167,270 $ 43.71 Granted 171,919 40.66 Released (152,740) 41.80 Forfeited (682) 40.27 Outstanding at March 31, 2022 185,767 $ 45.64 The following table provides additional information concerning restricted stock activity, including performance-based and market-based shares, and stock options: Three Months Ended March 31, Restricted Stock 2022 2021 Weighted-average grant date fair value $ 40.66 $ 43.68 Total fair value of restricted shares that vested (in thousands) $ 6,906 $ 8,967

Financing (Tables)

Financing (Tables)	3 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
Schedule of Short-term Debt	Short-term debt outstanding consists of: March 31, December 31, Short-term Debt 2022 2021 (In thousands) PNM Revolving Credit Facility $ 4,700 $ 7,400 TNMP Revolving Credit Facility 75,000 400 PNMR Revolving Credit Facility 6,300 54,900 $ 86,000 $ 62,700

Pension and Other Postretirem_2

Pension and Other Postretirement Benefit Plans (Tables)	3 Months Ended
	Mar. 31, 2022
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 March 31, Pension Plan OPEB Plan Executive Retirement Program 2022 2021 2022 2021 2022 2021 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ 2 $ 6 $ — $ — Interest cost 4,214 4,036 479 477 90 90 Expected return on plan assets (7,141) (7,133) (1,088) (1,042) — — Amortization of net loss 3,949 4,541 — — 82 100 Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 1,022 $ 1,444 $ (607) $ (559) $ 172 $ 190 The following table presents the components of the TNMP Plans’ net periodic benefit cost: Three Months Ended March 31, Pension Plan OPEB Plan Executive Retirement Program 2022 2021 2022 2021 2022 2021 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ 9 $ 11 $ — $ — Interest cost 430 435 77 77 3 4 Expected return on plan assets (618) (795) (104) (102) — — Amortization of net (gain) loss 233 312 (130) (80) — 9 Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 45 $ (48) $ (148) $ (94) $ 3 $ 13

Regulatory and Rate Matters (Ta

Regulatory and Rate Matters (Tables)	3 Months Ended
	Mar. 31, 2022
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) March 12, 2021 $ 112.6 $ 14.1 September 20, 2021 $ 41.2 $ 6.3 March 25, 2022 $ 95.6 $ 14.2

Lease Commitments (Tables)

Lease Commitments (Tables)	3 Months Ended
	Mar. 31, 2022
Leases [Abstract]
Assets and Liabilities, Lessee	Information related to the Company’s operating leases recorded on the Condensed Consolidated Balance Sheets is presented below: March 31, 2022 December 31, 2021 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating leases: Operating lease assets, net of amortization $ 69,022 $ 4,782 $ 74,126 $ 73,903 $ 5,264 $ 79,511 Current portion of operating lease liabilities 25,826 1,853 27,722 25,278 1,882 27,218 Long-term portion of operating lease liabilities 44,377 2,713 47,369 52,552 3,155 55,993 March 31, 2022 December 31, 2021 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Financing leases: Non-utility property $ 15,613 $ 16,232 $ 32,188 $ 15,171 $ 16,181 $ 31,695 Accumulated depreciation (5,282) (5,679) (11,171) (4,550) (4,923) (9,660) Non-utility property, net 10,331 10,553 21,017 10,621 11,258 22,035 Other current liabilities 2,818 2,975 5,881 2,731 2,994 5,813 Other deferred credits 7,373 7,586 15,008 7,732 8,273 16,075 Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities as of March 31, 2022 is presented below: PNM TNMP PNMR Consolidated Weighted average remaining lease term (years): Operating leases 6.23 2.75 6.02 Financing leases 4.10 3.93 4.00 Weighted average discount rate: Operating leases 4.03 % 4.00 % 4.02 % Financing leases 2.62 % 2.71 % 2.66 %
Lease, Cost	Information for the components of lease expense is as follows: Three Months Ended March 31, 2022 PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: $ 6,683 $ 528 $ 7,237 Amounts capitalized (185) (469) (654) Total operating lease expense 6,498 59 6,583 Financing lease cost: Amortization of right-of-use assets 732 757 1,511 Interest on lease liabilities 68 73 141 Amounts capitalized (497) (717) (1,213) Total financing lease expense 303 113 439 Variable lease expense 106 — 106 Short-term lease expense (1) 1,132 — 1,169 Total lease expense for the period $ 8,039 $ 172 $ 8,297 (1) Includes expense of $1.1 million for the three months ended March 31, 2022 for rental of temporary cooling towers associated with the SJGS Unit 1 outage. These amounts are offset with insurance reimbursements of $1.1 million for the three months ended March 31, 2022. For additional information on the SJGS Unit 1 outage see Note 12. Three Months Ended March 31, 2021 PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: $ 6,735 $ 653 $ 7,429 Amounts capitalized (226) (559) (785) Total operating lease expense 6,509 94 6,644 Financing lease cost: Amortization of right-of-use assets 532 613 1,167 Interest on lease liabilities 62 76 139 Amounts capitalized (368) (625) (993) Total financing lease expense 226 64 313 Variable lease expense 63 — 63 Short-term lease expense 124 2 132 Total lease expense for the period $ 6,922 $ 160 $ 7,152
Schedule of Leases, Supplemental Cash Flows	Supplemental cash flow information related to the Company’s leases is as follows: Three Months Ended Three Months Ended March 31, 2022 March 31, 2021 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 $ 9,244 $ 49 $ 9,318 $ 9,246 $ 97 $ 9,401 Operating cash flows from financing leases 22 8 31 21 8 30 Finance cash flows from financing leases 260 104 386 186 71 278 Non-cash information related to right-of-use assets obtained in exchange for lease obligations: Operating leases $ 1,079 $ — $ 1,079 $ — $ 317 $ 317 Financing leases 441 51 492 758 387 1,164
Lessee, Operating Lease, Liability, Maturity	Future expected lease payments are shown below: As of March 31, 2022 PNM TNMP PNMR Consolidated Financing Operating Financing Operating Financing Operating (In thousands) Remainder of 2022 $ 2,293 $ 16,918 $ 2,435 $ 1,496 $ 4,797 $ 18,630 2023 2,952 17,778 3,028 1,546 6,035 19,558 2024 2,267 7,953 2,557 943 4,838 8,958 2025 1,450 6,992 1,648 770 3,100 7,802 2026 1,048 6,928 844 76 1,892 7,042 Later years 801 22,132 613 — 1,414 22,315 Total minimum lease payments 10,811 78,701 11,125 4,831 22,076 84,305 Less: Imputed interest 620 8,498 564 265 1,187 9,214 Lease liabilities as of March 31, 2022 $ 10,191 $ 70,203 $ 10,561 $ 4,566 $ 20,889 $ 75,091
Finance Lease, Liability, Maturity	Future expected lease payments are shown below: As of March 31, 2022 PNM TNMP PNMR Consolidated Financing Operating Financing Operating Financing Operating (In thousands) Remainder of 2022 $ 2,293 $ 16,918 $ 2,435 $ 1,496 $ 4,797 $ 18,630 2023 2,952 17,778 3,028 1,546 6,035 19,558 2024 2,267 7,953 2,557 943 4,838 8,958 2025 1,450 6,992 1,648 770 3,100 7,802 2026 1,048 6,928 844 76 1,892 7,042 Later years 801 22,132 613 — 1,414 22,315 Total minimum lease payments 10,811 78,701 11,125 4,831 22,076 84,305 Less: Imputed interest 620 8,498 564 265 1,187 9,214 Lease liabilities as of March 31, 2022 $ 10,191 $ 70,203 $ 10,561 $ 4,566 $ 20,889 $ 75,091

Related Party Transactions (Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2022
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 March 31, 2022 2021 (In thousands) Services billings: PNMR to PNM $ 27,693 $ 26,225 PNMR to TNMP 10,304 10,365 PNM to TNMP 93 118 TNMP to PNMR 35 12 PNMR to NMRD 64 55 Renewable energy purchases: PNM from NMRD 2,621 2,585 Interconnection and facility study billings: PNM to NMRD — — PNM to PNMR — — NMRD to PNM — 1,276 Interest billings: PNMR to PNM 7 — PNM to PNMR 23 36 PNMR to TNMP 45 — Income tax sharing payments: PNMR to PNM — — TNMP to PNMR — —

Equity Method Investment (Table

Equity Method Investment (Tables)	3 Months Ended
	Mar. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Marketable Securities	Summarized financial information for NMRD is as follows: Results of Operations Three Months Ended March 31, 2022 2021 (In thousands) Operating revenues $ 2,796 $ 2,750 Operating expenses 2,404 2,522 Net earnings $ 392 $ 228 Financial Position March 31, December 31, 2022 2021 (In thousands) Current assets $ 5,827 $ 10,729 Net property, plant, and equipment 164,733 166,495 Non-current assets 9,653 2,289 Total assets 180,213 179,513 Current liabilities 1,148 824 Non-current liabilities 377 373 Owners’ equity $ 178,688 $ 178,316

Significant Accounting Polici_3

Significant Accounting Policies and Responsibility for Financial Statements (Details) - USD ($)	1 Months Ended		3 Months Ended
	Feb. 28, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Accounting Policies [Abstract]
Payment defaults under agreements			$ 0
Dividends declared per common share (dollars per share)	$ 0.3475	$ 0.3275	$ 0.3475	$ 0.3275

Segment Information - Summarize

Segment Information - Summarized Financial Information (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2022USD ($)segment	Mar. 31, 2021USD ($)	Dec. 31, 2021USD ($)
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	$ 444,118	$ 364,707
Other operating expenses	131,872	136,271
Depreciation and amortization	75,764	69,874
Operating income	68,068	43,166
Interest income	4,292	3,559
Other income (deductions)	(24,484)	1,930
Interest charges	(26,220)	(25,884)
Earnings before Income Taxes	21,656	22,771
Income taxes (benefit)	2,438	1,566
Net Earnings	19,218	21,205
Valencia non-controlling interest	(3,095)	(3,494)
Subsidiary preferred stock dividends	(132)	(132)
Net Earnings Available for PNM Common Stock	15,991	17,579
Total Assets	8,727,686	7,943,309	$ 8,666,885
Goodwill	$ 278,297	278,297	278,297
PNM
Segment Reporting Information [Line Items]
Number of operating segments | segment	1
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	$ 338,709	271,213
Depreciation and amortization	45,790	41,949
Operating income	45,016	33,050
Interest income	3,133	3,595
Interest charges	(14,572)	(12,893)
Earnings before Income Taxes	8,361	24,996
Income taxes (benefit)	823	2,834
Net Earnings	7,538	22,162
Valencia non-controlling interest	(3,095)	(3,494)
Subsidiary preferred stock dividends	(132)	(132)
Net Earnings Available for PNM Common Stock	4,311	18,536
Total Assets	6,040,088		6,060,133
Goodwill	$ 51,632		51,632
TNMP
Segment Reporting Information [Line Items]
Number of operating segments | segment	1
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	$ 105,409	93,494
Cost of energy	29,600	26,510
Depreciation and amortization	23,642	22,190
Operating income	24,242	17,025
Interest income	1,182	0
Interest charges	(9,150)	(8,475)
Earnings before Income Taxes	17,211	9,612
Income taxes (benefit)	2,151	877
Net Earnings	15,060	8,735
Total Assets	2,450,081		2,364,772
Goodwill	226,665		$ 226,665
PNM
Segment Reporting Information, Profit (Loss) [Abstract]
Other operating expenses	109,089	107,328
Depreciation and amortization	45,790	41,949
Operating income	45,016	33,050
Interest income	3,133	3,595
Other income (deductions)	(25,216)	1,244
Interest charges	(14,572)	(12,893)
Earnings before Income Taxes	8,361	24,996
Income taxes (benefit)	823	2,834
Net Earnings	7,538	22,162
Valencia non-controlling interest	(3,095)	(3,494)
Subsidiary preferred stock dividends	(132)	(132)
Net Earnings Available for PNM Common Stock	4,311	18,536
Total Assets	6,040,088	5,561,146
Goodwill	51,632	51,632
TNMP
Segment Reporting Information, Profit (Loss) [Abstract]
Other operating expenses	27,925	27,769
Depreciation and amortization	23,642	22,190
Operating income	24,242	17,025
Interest income	1,182	0
Other income (deductions)	937	1,062
Interest charges	(9,150)	(8,475)
Earnings before Income Taxes	17,211	9,612
Income taxes (benefit)	2,151	877
Net Earnings	15,060	8,735
Valencia non-controlling interest	0	0
Subsidiary preferred stock dividends	0	0
Net Earnings Available for PNM Common Stock	15,060	8,735
Total Assets	2,450,081	2,163,250
Goodwill	226,665	226,665
Corporate and Other
Segment Reporting Information, Profit (Loss) [Abstract]
Other operating expenses	(5,142)	1,174
Depreciation and amortization	6,332	5,735
Operating income	(1,190)	(6,909)
Interest income	(23)	(36)
Other income (deductions)	(205)	(376)
Interest charges	(2,498)	(4,516)
Earnings before Income Taxes	(3,916)	(11,837)
Income taxes (benefit)	(536)	(2,145)
Net Earnings	(3,380)	(9,692)
Valencia non-controlling interest	0	0
Subsidiary preferred stock dividends	0	0
Net Earnings Available for PNM Common Stock	(3,380)	(9,692)
Total Assets	237,517	218,913
Goodwill	0	0
Energy
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	444,118	364,707
Cost of energy	168,414	115,396
Utility margin	275,704	249,311
Energy | PNM
Segment Reporting Information, Profit (Loss) [Abstract]
Cost of energy	138,814	88,886
Energy | PNM
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	338,709	271,213
Cost of energy	138,814	88,886
Utility margin	199,895	182,327
Energy | TNMP
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	105,409	93,494
Cost of energy	29,600	26,510
Utility margin	75,809	66,984
Energy | Corporate and Other
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	0	0
Cost of energy	0	0
Utility margin	$ 0	$ 0

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	$ 2,222,929	$ 2,108,474
Total Other Comprehensive Income (Loss)	(4,644)	(3,159)
Ending balance	2,169,800	2,088,226
Total
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(71,936)	(79,183)
Amounts reclassified from AOCI (pre-tax)	299	(2,155)
Income tax impact of amounts reclassified	(76)	547
Other OCI changes (pre-tax)	(6,524)	(2,079)
Income tax impact of other OCI changes	1,657	528
Total Other Comprehensive Income (Loss)	(4,644)	(3,159)
Ending balance	(76,580)	(82,342)
Fair Value Adjustment for Cash Flow Hedges
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	0	(672)
Amounts reclassified from AOCI (pre-tax)	0	(624)
Income tax impact of amounts reclassified	0	158
Other OCI changes (pre-tax)	0	1,247
Income tax impact of other OCI changes	0	(317)
Total Other Comprehensive Income (Loss)	0	464
Ending balance	0	(208)
PNM
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	2,015,264	1,863,752
Total Other Comprehensive Income (Loss)	(4,644)	(3,623)
Ending balance	2,013,794	1,876,916
PNM | Total
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(71,936)	(78,511)
Amounts reclassified from AOCI (pre-tax)	299	(1,531)
Income tax impact of amounts reclassified	(76)	389
Other OCI changes (pre-tax)	(6,524)	(3,326)
Income tax impact of other OCI changes	1,657	845
Total Other Comprehensive Income (Loss)	(4,644)	(3,623)
Ending balance	(76,580)	(82,134)
PNM | Unrealized Gains on Available-for-Sale Securities
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	11,715	20,403
Amounts reclassified from AOCI (pre-tax)	(1,477)	(3,618)
Income tax impact of amounts reclassified	375	919
Other OCI changes (pre-tax)	(6,524)	(3,326)
Income tax impact of other OCI changes	1,657	845
Total Other Comprehensive Income (Loss)	(5,969)	(5,180)
Ending balance	5,746	15,223
PNM | Pension Liability Adjustment
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(83,651)	(98,914)
Amounts reclassified from AOCI (pre-tax)	1,776	2,087
Income tax impact of amounts reclassified	(451)	(530)
Other OCI changes (pre-tax)	0	0
Income tax impact of other OCI changes	0	0
Total Other Comprehensive Income (Loss)	1,325	1,557
Ending balance	$ (82,326)	$ (97,357)

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Earnings Per Share [Abstract]
Net Earnings Attributable to PNMR	$ 15,991	$ 17,579
Average Number of Common Shares:
Outstanding during period (in shares)	85,835	85,835
Vested awards of restricted stock (in shares)	256	196
Average Shares – Basic (in shares)	86,091	86,031
Dilutive Effect of Common Stock Equivalents:
Restricted stock (in shares)	80	24
Average Shares – Diluted (in shares)	86,171	86,055
Net Earnings Per Share of Common Stock:
Basic (in dollars per share)	$ 0.19	$ 0.20
Diluted (in dollars per share)	$ 0.19	$ 0.20

Electric Operating Revenues - N

Electric Operating Revenues - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022USD ($)utility	Mar. 31, 2021USD ($)	Dec. 31, 2021USD ($)
Disaggregation of Revenue [Line Items]
Number of regulated utilities | utility	2
Accounts receivable, allowance for credit loss, period increase	$ (0.9)	$ 1.6
Other receivables, allowance for credit loss, period increase	0	$ 0
Contract assets	3.4		$ 0.6
Texas-New Mexico Power Company
Disaggregation of Revenue [Line Items]
Regulatory assets	0.8		0.8
PNM
Disaggregation of Revenue [Line Items]
Accounts receivable	$ 77.7		$ 86.8

Electric Operating Revenues - D

Electric Operating Revenues - Disaggregation of revenues (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 384,493	$ 346,585
Alternative revenue programs	(5,505)	(909)
Other electric operating revenue	65,130	19,031
Revenues	444,118	364,707
PNM
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	275,644	251,206
Alternative revenue programs	(2,065)	976
Other electric operating revenue	65,130	19,031
Revenues	338,709	271,213
TNMP
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	108,849	95,379
Alternative revenue programs	(3,440)	(1,885)
Other electric operating revenue	0	0
Revenues	105,409	93,494
Energy
Disaggregation of Revenue [Line Items]
Revenues	444,118	364,707
Energy | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	151,942	149,763
Energy | Commercial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	121,107	111,363
Energy | Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	31,522	26,193
Energy | Public authority
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	5,952	6,069
Energy | Economy energy service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	8,940	10,581
Energy | PNM | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	112,574	114,669
Energy | PNM | Commercial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	88,004	81,934
Energy | PNM | Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	23,132	18,900
Energy | PNM | Public authority
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4,426	4,587
Energy | PNM | Economy energy service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	8,940	10,581
Energy | TNMP | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	39,368	35,094
Energy | TNMP | Commercial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	33,103	29,429
Energy | TNMP | Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	8,390	7,293
Energy | TNMP | Public authority
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,526	1,482
Energy | TNMP | Economy energy service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Transmission
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	60,055	38,624
Transmission | PNM
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	34,526	17,503
Transmission | TNMP
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	25,529	21,121
Miscellaneous
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4,975	3,992
Miscellaneous | PNM
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4,042	3,032
Miscellaneous | TNMP
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 933	$ 960

Variable Interest Entities (Det

Variable Interest Entities (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2022USD ($)MW	Mar. 31, 2021USD ($)	Dec. 31, 2021USD ($)	Jan. 31, 2016USD ($)
Results of Operations
Operating revenues	$ 444,118	$ 364,707
Operating expenses	376,050	321,541
Earnings attributable to non-controlling interest	3,095	3,494
Financial Position
Current assets	301,145		$ 324,600
Assets	8,727,686	7,943,309	8,666,885
Current liabilities	673,043		664,213
Owners’ equity – non-controlling interest	54,268		55,405
San Juan Generating Station | Coal supply
Variable Interest Entity [Line Items]
Cash used to support bank letter or credit arrangement				$ 30,300
PNM
Results of Operations
Operating revenues	338,709	271,213
Operating expenses	293,693	238,163
Earnings attributable to non-controlling interest	3,095	3,494
Financial Position
Current assets	243,465		266,689
Assets	6,040,088		6,060,133
Current liabilities	484,339		495,902
Owners’ equity – non-controlling interest	54,268		55,405
PNM | Valencia
Variable Interest Entity [Line Items]
Payment for fixed costs	4,800	4,900
Payment for variable costs	$ 100	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	$ 4,932	5,127
Operating expenses	1,837	1,633
Earnings attributable to non-controlling interest	3,095	$ 3,494
Financial Position
Current assets	3,206		3,042
Net property, plant, and equipment	52,198		52,908
Assets	55,404		55,950
Current liabilities	1,136		545
Owners’ equity – non-controlling interest	$ 54,268		$ 55,405
PNM | Purchased through May 2028 | Valencia
Variable Interest Entity [Line Items]
Number of megawatts purchased (in megawatts) | MW	155

Fair Value of Derivative and _3

Fair Value of Derivative and Other Financial Instruments - Narrative (Details)	Mar. 18, 2022MW	Feb. 17, 2022MW	Mar. 31, 2022USD ($)MWgal	Mar. 31, 2021USD ($)	Dec. 31, 2021USD ($)MWpower_purchase_agreement	Dec. 31, 2021USD ($)MWhMWpower_purchase_agreementgal
Debt Securities, Available-for-sale [Line Items]
Number of purchase power agreements | power_purchase_agreement					3
Number of purchase power agreements, non derivatives | power_purchase_agreement						2
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
Number of megawatts available in purchase power agreement (in megawatts) | MW	65	327
Expected exposure to market risk (in megawatts) | MW			65
Power to be sold to third party (in megawatts) | MW			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			$ (8,900,000)	$ 1,100,000
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						122,400
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			$ 200,000
Derivative asset, gross asset					500,000	$ 500,000
Other current assets			183,000		684,000	684,000
Current derivative liability			3,852,000		$ 2,275,000	$ 2,275,000
PNM | Commodity derivatives | Designated as Hedging Instrument | Cost of energy
Debt Securities, Available-for-sale [Line Items]
Total gain			100,000	$ 100,000
PNM | Portfolio One
Debt Securities, Available-for-sale [Line Items]
Number of megawatts available in purchase power agreement (in megawatts) | MW					85	85
PNM | Portfolio Three
Debt Securities, Available-for-sale [Line Items]
Number of megawatts available in purchase power agreement (in megawatts) | MW					40	40
PNM | Portfolio Two
Debt Securities, Available-for-sale [Line Items]
Number of megawatts available in purchase power agreement (in megawatts) | MW					150	150
PNM | Fuel and purchased power costs | Commodity derivatives | Designated as Hedging Instrument
Debt Securities, Available-for-sale [Line Items]
Other current assets			0		$ 200,000	$ 200,000
Current derivative liability			$ 3,700,000		1,800,000	1,800,000
PNM | Tri-State
Debt Securities, Available-for-sale [Line Items]
Power to be sold to third party (in megawatts) | MW			100
PNM | Recurring
Debt Securities, Available-for-sale [Line Items]
Available-for-sale debt securities			$ 431,097,000		463,126,000	463,126,000
Nuclear Decommissioning Trust | PNM | Recurring
Debt Securities, Available-for-sale [Line Items]
Available-for-sale debt securities			364,100,000		394,500,000	394,500,000
Mine Reclamation Trust | PNM | Recurring
Debt Securities, Available-for-sale [Line Items]
Available-for-sale debt securities			$ 67,000,000		$ 68,600,000	$ 68,600,000

Fair Value of Derivative and _4

Fair Value of Derivative and Other Financial Instruments - Overview and Commodity Derivatives (Details) - PNM - Designated as Hedging Instrument - Commodity derivatives - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Other current assets	$ 183	$ 684
Other deferred charges	0	0
Derivative asset	183	684
Other current liabilities	(3,852)	(2,275)
Other deferred credits	0	0
Derivative liability	(3,852)	(2,275)
Net	$ (3,669)	$ (1,591)

Fair Value of Derivative and _5

Fair Value of Derivative and Other Financial Instruments - Investments in NDT and Gross Realized Losses (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Equity securities:
Net gains from equity securities sold	$ 5,006	$ 2,022
Net (losses) from equity securities still held	(22,035)	(3,166)
Total net (losses) on equity securities	(17,029)	(1,144)
Available-for-sale debt securities:
Net gains (losses) on debt securities	(9,544)	2,112
Net gains (losses) on investment securities	$ (26,573)	$ 968

Fair Value Measures and Disclos

Fair Value Measures and Disclosures - Gross Realized (Losses) (Details) - PNM - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Debt Securities, Available-for-sale [Line Items]
Proceeds from sales	$ 125,246	$ 123,596
Gross realized gains	10,178	8,692
Gross realized (losses)	$ (5,840)	$ (3,443)

Fair Value of Derivative and _6

Fair Value of Derivative and Other Financial Instruments - Maturities of Debt Securities (Details) - PNMR and PNM $ in Thousands	Mar. 31, 2022USD ($)
Available-for-Sale
Within 1 year	$ 32,919
After 1 year through 5 years	70,710
After 5 years through 10 years	87,507
After 10 years through 15 years	16,377
After 15 years through 20 years	12,815
After 20 years	34,865
Available-for-sale debt securities	$ 255,193

Fair Value of Derivative and _7

Fair Value of Derivative and Other Financial Instruments - Items Recorded and Presented by Level of Hierarchy (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of long-term debt	$ 3,708,586	$ 3,915,010
Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of long-term debt	3,799,460	3,698,919
PNM
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of long-term debt	1,785,939	1,975,987
PNM | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of long-term debt	1,881,633	1,881,110
TNMP
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of long-term debt	922,647	1,039,023
TNMP | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of long-term debt	918,025	918,050
Recurring | PNM
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	431,097	463,126
Investments, unrealized gain	7,740	15,741
Recurring | PNM | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	224,720	197,741
Recurring | PNM | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	206,377	265,385
Recurring | PNM | Cash and cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	13,935	7,895
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	13,935	7,895
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	84,240	97,626
Recurring | PNM | Corporate stocks, common | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	84,240	97,626
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	8,253	9,114
Recurring | PNM | Corporate stocks, preferred | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	3,349	3,775
Recurring | PNM | Corporate stocks, preferred | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	4,904	5,339
Recurring | PNM | Mutual funds and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	69,476	75,285
Recurring | PNM | Mutual funds and other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	69,476	75,241
Recurring | PNM | Mutual funds and other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	0	44
Recurring | PNM | U.S. government
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	56,695	43,128
Investments, unrealized gain	283	214
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	53,720	13,204
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	2,975	29,924
Recurring | PNM | International government
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	13,004	16,001
Investments, unrealized gain	832	1,508
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	13,004	16,001
Recurring | PNM | Municipals
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	43,828	47,050
Investments, unrealized gain	227	1,807
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	43,828	47,050
Recurring | PNM | Corporate and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale debt securities	141,666	167,027
Investments, unrealized gain	6,398	12,212
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	0
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	$ 141,666	$ 167,027

Stock-Based Compensation - Narr

Stock-Based Compensation - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022USD ($)shares
Restricted Shares and Performance Based Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized expense related to stock awards | $	$ 6.8
Period of time stock expense is expected to be recognized	2 years
Executive | Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum number of shares awarded in year two (in shares)	142,047
Maximum number of shares awarded in year three (in shares)	152,414
Maximum number of shares awarded in year four (in shares)	173,051
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)	92,343
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

Stock-Based Compensation (Detai

Stock-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
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)	$ 0.3475	$ 0.3275
Risk-free interest rate	1.46%	0.32%
Restricted Stock
Restricted Stock, Shares
Outstanding at beginning of period (in shares)	167,270
Granted (in shares)	171,919
Exercised (in shares)	(152,740)
Forfeited (in shares)	(682)
Outstanding at end of period (in shares)	185,767
Restricted Stock, Weighted- Average Grant Date Fair Value
Outstanding at beginning of period (in dollars per share)	$ 43.71
Granted (in dollars per share)	40.66	$ 43.68
Exercised (in dollars per share)	41.80
Forfeited (in dollars per share)	40.27
Outstanding at end of period (in dollars per share)	45.64
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Weighted-average grant date fair value (in dollars per share)	$ 40.66	$ 43.68
Total fair value of restricted shares that vested	$ 6,906	$ 8,967
Market-Based Shares
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Risk-free interest rate	0.00%	0.29%
Dividend yield	0.00%	2.76%
Expected volatility	0.00%	33.69%

Financing - Financing Activitie

Financing - Financing Activities (Details)	Jan. 24, 2022USD ($)	Mar. 09, 2021USD ($)	Dec. 22, 2020USD ($)	Mar. 31, 2022	Dec. 31, 2021USD ($)	Apr. 27, 2022USD ($)bond_series	Apr. 21, 2022USD ($)	Jan. 31, 2022USD ($)	May 18, 2021USD ($)	Mar. 09, 2018USD ($)
Debt Instrument [Line Items]
Financing capacity								$ 40,000,000
Subsequent event
Debt Instrument [Line Items]
Remaining borrowing capacity							$ 705,500,000
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 | Subsequent event
Debt Instrument [Line Items]
Remaining borrowing capacity							400,000,000
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							$ 0
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
Proceeds from long-term lines of credit	$ 100,000,000				$ 900,000,000
Line of credit | PNM and TNMP
Debt Instrument [Line Items]
Ratio of debt to capital (less than or equal to)				65.00%
Unsecured Debt | PNMR 2018 SUNS 3.25% due March 2021
Debt Instrument [Line Items]
Aggregate principal amount										$ 300,000,000
Stated interest rate										3.25%
Repayments of debt		$ 80,000,000
Bonds | TNMP 2022 Bond Purchase Agreement at 4.13% Due May 12, 2022 | Subsequent event
Debt Instrument [Line Items]
Stated interest rate						4.13%
Bonds | TNMP 2022 Bond Purchase Agreement at 3.81% Due July 28, 2032 | Subsequent event
Debt Instrument [Line Items]
Stated interest rate						3.81%
Bonds | PNMR 2021 Delayed-Draw Term Loan
Debt Instrument [Line Items]
Variable interest rate				1.29%
Bonds | PNM | PNM 2021 75 Million Term Loan
Debt Instrument [Line Items]
Variable interest rate				1.28%
Bonds | Texas-New Mexico Power Company | TNMP 2022 Bond Purchase Agreement | Subsequent event
Debt Instrument [Line Items]
Aggregate principal amount						$ 160,000,000
Debt instrument, series of bond issuance | bond_series						2
Bonds | Texas-New Mexico Power Company | TNMP 2022 Bond Purchase Agreement at 4.13% Due May 12, 2022 | Subsequent event
Debt Instrument [Line Items]
Aggregate principal amount						$ 65,000,000
Bonds | Texas-New Mexico Power Company | TNMP 2022 Bond Purchase Agreement at 3.81% Due July 28, 2032 | Subsequent event
Debt Instrument [Line Items]
Aggregate principal amount						$ 95,000,000

Financing - Short-term Debt and

Financing - Short-term Debt and Liquidity (Details)	Mar. 11, 2022USD ($)extension_option	Dec. 31, 2017USD ($)derivative	Apr. 21, 2022USD ($)	Mar. 31, 2022USD ($)	Mar. 10, 2022USD ($)	Jan. 31, 2022USD ($)	Dec. 31, 2021USD ($)	Mar. 23, 2021
Short-term Debt [Line Items]
Financing capacity						$ 40,000,000
Letters of credit outstanding				$ 3,400,000
Notes payable, related parties				$ 6,300,000			$ 6,400,000
Variable Rate Short-Term Debt
Short-term Debt [Line Items]
Term of derivatives		4 years
Aggregate principal amount		$ 50,000,000
PNM Revolving Credit Facility
Short-term Debt [Line Items]
Line of credit facility, interest rate at period end				1.70%
PNMR Revolving Credit Facility | WEB LOC Facility
Short-term Debt [Line Items]
Letters of credit outstanding				$ 30,300,000
PNM
Short-term Debt [Line Items]
Letters of credit outstanding				0
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]
Letters of credit outstanding				0
TNMP
Short-term Debt [Line Items]
Letters of credit outstanding				0
Notes payable, related parties				$ 700,000			0
TNMP | TNMP Revolving Credit Facility
Short-term Debt [Line Items]
Line of credit facility, interest rate at period end				1.25%
PNMR Development
Short-term Debt [Line Items]
Notes payable, related parties				$ 0			$ 0
PNMR Development | PNMR Revolving Credit Facility
Short-term Debt [Line Items]
Line of credit facility, interest rate at period end				1.95%
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	$ 100,000,000				$ 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			$ 6,300,000
Remaining borrowing capacity			705,500,000
Subsequent event | PNMR
Short-term Debt [Line Items]
Remaining borrowing capacity			265,500,000
Consolidated invested cash			900,000
Subsequent event | PNM
Short-term Debt [Line Items]
Notes payable, related parties			0
Remaining borrowing capacity			400,000,000
Consolidated invested cash			8,700,000
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			0
Consolidated invested cash			0
Subsequent event | PNMR Development
Short-term Debt [Line Items]
Notes payable, related parties			$ 30,200,000

Financing - Schedule of Short-T

Financing - Schedule of Short-Term Debt (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Short-term Debt [Line Items]
Short-term debt	$ 86,000	$ 62,700
PNM
Short-term Debt [Line Items]
Short-term debt	4,700	7,400
Texas-New Mexico Power Company
Short-term Debt [Line Items]
Short-term debt	75,000	400
PNM Revolving Credit Facility | PNM
Short-term Debt [Line Items]
Short-term debt	4,700	7,400
TNMP Revolving Credit Facility | Texas-New Mexico Power Company
Short-term Debt [Line Items]
Short-term debt	75,000	400
PNMR Revolving Credit Facility
Short-term Debt [Line Items]
Short-term debt	$ 6,300	$ 54,900

Pension and Other Postretirem_3

Pension and Other Postretirement Benefit Plans - Schedule of Net Periodic Benefit Costs (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
PNM | Pension Plan
Components of Net Periodic Benefit Cost
Service cost	$ 0	$ 0
Interest cost	4,214	4,036
Expected return on plan assets	(7,141)	(7,133)
Amortization of net loss	3,949	4,541
Amortization of prior service cost	0	0
Net Periodic Benefit Cost (Income)	1,022	1,444
PNM | OPEB Plan
Components of Net Periodic Benefit Cost
Service cost	2	6
Interest cost	479	477
Expected return on plan assets	(1,088)	(1,042)
Amortization of net loss	0	0
Amortization of prior service cost	0	0
Net Periodic Benefit Cost (Income)	(607)	(559)
PNM | Executive Retirement Program
Components of Net Periodic Benefit Cost
Service cost	0	0
Interest cost	90	90
Expected return on plan assets	0	0
Amortization of net loss	82	100
Amortization of prior service cost	0	0
Net Periodic Benefit Cost (Income)	172	190
Texas-New Mexico Power Company | Pension Plan
Components of Net Periodic Benefit Cost
Service cost	0	0
Interest cost	430	435
Expected return on plan assets	(618)	(795)
Amortization of net loss	233	312
Amortization of prior service cost	0	0
Net Periodic Benefit Cost (Income)	45	(48)
Texas-New Mexico Power Company | OPEB Plan
Components of Net Periodic Benefit Cost
Service cost	9	11
Interest cost	77	77
Expected return on plan assets	(104)	(102)
Amortization of net loss	(130)	(80)
Amortization of prior service cost	0	0
Net Periodic Benefit Cost (Income)	(148)	(94)
Texas-New Mexico Power Company | Executive Retirement Program
Components of Net Periodic Benefit Cost
Service cost	0	0
Interest cost	3	4
Expected return on plan assets	0	0
Amortization of net loss	0	9
Amortization of prior service cost	0	0
Net Periodic Benefit Cost (Income)	$ 3	$ 13

Pension and Other Postretirem_4

Pension and Other Postretirement Benefit Plans - Narrative (Details) - USD ($)	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Pension Plan | PNM
Defined Benefit Plan Disclosure [Line Items]
Contributions by employer	$ 0	$ 0
Expected employer contributions, remainder of fiscal year	$ 0
Pension Plan | PNM | Maximum
Defined Benefit Plan Disclosure [Line Items]
Assumptions used calculating net periodic benefit cost, discount rate	2.90%
Pension Plan | Texas-New Mexico Power Company
Defined Benefit Plan Disclosure [Line Items]
Contributions by employer	$ 0	0
Estimated employer contributions for remainder of fiscal year through year 5	$ 0
Pension Plan | Texas-New Mexico Power Company | Maximum
Defined Benefit Plan Disclosure [Line Items]
Assumptions used calculating net periodic benefit cost, discount rate	2.90%
OPEB Plan | PNM
Defined Benefit Plan Disclosure [Line Items]
Contributions by employer	$ 0	0
Disbursements by employer	900,000	900,000
Disbursements by employer, remainder of fiscal year	3,200,000
Disbursements by employer, after current year	11,900,000
OPEB Plan | Texas-New Mexico Power Company
Defined Benefit Plan Disclosure [Line Items]
Contributions by employer	0	0
Estimated employer contributions for remainder of fiscal year through year 5	0
Executive Retirement Program | PNM
Defined Benefit Plan Disclosure [Line Items]
Disbursements by employer		400,000
Disbursements by employer, remainder of year	1,300,000
Disbursements by employer, after current year	4,700,000
Executive Retirement Program | Texas-New Mexico Power Company
Defined Benefit Plan Disclosure [Line Items]
Disbursements by employer, remainder of year	100,000
Executive Retirement Program | Texas-New Mexico Power Company | Maximum
Defined Benefit Plan Disclosure [Line Items]
Disbursements by employer	$ 0	$ 0

Commitments and Contingencies -

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	Mar. 31, 2022	Dec. 31, 2021
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	$ 12.4	$ 13

Commitments and Contingencies_2

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

Commitments and Contingencies_3

Commitments and Contingencies - The Clean Air Act (Details)	Mar. 31, 2022T	Feb. 25, 2019parts_per_billion	Oct. 01, 2015parts_per_billion	Sep. 30, 2015parts_per_billion	Dec. 31, 1999state
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	70	75

Commitments and Contingencies_4

Commitments and Contingencies - Cooling Water Intake Structures (Details)	3 Months Ended
	Mar. 31, 2022option
Text Block [Abstract]
Number of options for meeting BTA standards	7

Commitments and Contingencies_5

Commitments and Contingencies - Coal Supply (Details) $ in Thousands	Feb. 17, 2022$ / T	Nov. 09, 2021USD ($)	Dec. 31, 2020USD ($)	Mar. 31, 2022USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Jan. 31, 2016USD ($)
Public Utilities, Commitments And Contingencies [Line Items]
Other current assets				$ 1,082	$ 1,635
PNM
Public Utilities, Commitments And Contingencies [Line Items]
Other current assets				995	1,456
PNM | Loss on long-term purchase commitment | Surface
Public Utilities, Commitments And Contingencies [Line Items]
Loss contingency accrual				66,600	67,400
PNM | Loss on long-term purchase commitment | Underground
Public Utilities, Commitments And Contingencies [Line Items]
Loss contingency accrual				28,300	27,900
PNM | Loss on long-term purchase commitment | San Juan Generating Station | Surface
Public Utilities, Commitments And Contingencies [Line Items]
Estimate of possible loss				72,900
PNM | Loss on long-term purchase commitment | San Juan Generating Station | Underground
Public Utilities, Commitments And Contingencies [Line Items]
Estimate of possible loss				34,900
Coal supply | San Juan Generating Station
Public Utilities, Commitments And Contingencies [Line Items]
Cash used to support bank letter or credit arrangement								$ 30,300
Coal supply | Four Corners
Public Utilities, Commitments And Contingencies [Line Items]
Payments for relief from obligations				75,000
Coal supply | PNM | San Juan Generating Station
Public Utilities, Commitments And Contingencies [Line Items]
Other current assets				10,000	20,400
Increase in price of coal per ton | $ / T	5
Coal supply | NM Capital | San Juan Generating Station
Public Utilities, Commitments And Contingencies [Line Items]
Requirement to post reclamation bonds				118,700
Cash used to support bank letter or credit arrangement				30,300
Increase in coal mine decommissioning liability | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory disallowance, additional amount recorded							$ 800
Increase in coal mine decommissioning liability | PNM | Surface
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory disallowance, additional amount recorded			$ 3,600
Decrease in coal mine decommissioning liability | PNM | Underground
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory disallowance, additional amount recorded			$ 100
Decrease in coal mine decommissioning liability | PNM | Four Corners
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory disallowance, additional amount recorded						$ 2,500
Mine Reclamation Trust | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Required contribution to reclamation trust, current fiscal year				7,000
Reclamation trust funding, year 2				0
Reclamation trust funding, year 3				0
Four Corners CSA | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Other commitment, due in first year					2,200
Other commitment, due in second year				2,100
Other commitment, due in third year				2,100
Other commitment, due in fourth year				2,100
San Juan Generating Station | Loss on long-term purchase commitment | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Annual funding post-term reclamation trust					$ 5,200
San Juan Generating Station | Coal-Fired Electricity Generating Facility Demolition And Remediation Ordinance | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Public Utilities, Initial Funding Requirement		$ 14,700
Loss Contingency, Surety Bond		$ 46,000
San Juan Generating Station and Four Corners | Mine Reclamation Trust | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Customer Reclamation Funding Cost, Maximum				$ 100,000

Commitments and Contingencies_6

Commitments and Contingencies - PVNGS Liability and Insurance Matters, Navajo Nation Allottee Matters and Texas Winter Storm (Details)	1 Months Ended	3 Months Ended
	Sep. 30, 2012landowner	Mar. 31, 2022USD ($)generating_unit	Dec. 31, 2021USD ($)	Dec. 01, 2015Allotment_Parcel	Jul. 13, 2015a	Jan. 22, 2015Allotment_Parcel
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	$ 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

Regulatory and Rate Matters - P

Regulatory and Rate Matters - PNM (Details) $ in Millions	Jan. 01, 2022USD ($)	Apr. 15, 2021USD ($)GWh	Jan. 29, 2021	Apr. 15, 2020USD ($)MMBTU	Mar. 31, 2022USD ($)$ / MWhMW	Mar. 31, 2021USD ($)	Jul. 29, 2020MW
Public Utilities, Commitments And Contingencies [Line Items]
Excess return on jurisdictional equity that would require refund					0.50%
PNM
Public Utilities, Commitments And Contingencies [Line Items]
Solar generation capacity (in megawatts)							650
Renewable Portfolio Standard | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Number of megawatts of Solar PV facilities					158
Current output in the geothermal facility (in megawatts)					11
Solar generation capacity (in megawatts)					211.8
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				94
Program costs related to energy efficiency, in year two | $				$ 31.4
Program costs related to energy efficiency, in year three | $				31
Program costs related to energy efficiency, in year four | $				$ 29.6
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 | $	$ 66.9
NMPRC | Renewable Energy Rider | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Recorded revenues from renewable rider | $					$ 14.5	$ 15.9
Maximum | Renewable Portfolio Standard | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Reasonable cost threshold in megawatts per hour | $ / MWh					60
Minimum | Renewable Portfolio Standard | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Profit incentive sliding scale multiplier				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					200
Red Mesa Wind | Renewable Portfolio Standard 2014 | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Number of megawatts for wind energy					102
La Joya Wind | Renewable Portfolio Standard | PNM
Public Utilities, Commitments And Contingencies [Line Items]
Number of megawatts for wind energy					140
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 | $		$ 0.8

Regulatory and Rate Matters - S

Regulatory and Rate Matters - SJGS, Fours Corners and PVNGS Leased Interest Abandonment Applications (Details) $ in Thousands

Mar. 18, 2022MW

Feb. 17, 2022MW

Apr. 02, 2021leaseMW

Feb. 03, 2021

Jan. 08, 2021USD ($)

Nov. 01, 2020USD ($)

Jul. 01, 2019USD ($)

Nov. 30, 2020USD ($)

Mar. 31, 2022USD ($)

Dec. 31, 2021USD ($)MWpower_purchase_agreement

Dec. 31, 2021USD ($)power_purchase_agreementMW

Apr. 14, 2022MW

Dec. 18, 2020USD ($)

Nov. 13, 2020MW

Sep. 28, 2020USD ($)

Jul. 29, 2020MW

Mar. 31, 2020USD ($)

Feb. 21, 2020USD ($)

Public Utilities, General Disclosures [Line Items]

Regulatory time frame for proposed PPAs and battery storage agreements

6 months

Number of purchase power agreements | power_purchase_agreement

3

Regulatory assets

$ 511,639

$ 514,258

$ 514,258

Regulatory liabilities

845,701

841,393

$ 841,393

COVID-19

Public Utilities, General Disclosures [Line Items]

Temporary mandatory moratorium on disconnection period

100 days

Disconnection transition period

90 days

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 purchase power agreements | power_purchase_agreement

3

Number of megawatts available in purchase power agreement (in megawatts) | MW

65

327

Number of leases under which lease term was extended | lease

5

Regulatory assets

426,177

428,981

$ 428,981

Regulatory liabilities

$ 651,495

653,830

653,830

PNM | Minimum

Public Utilities, General Disclosures [Line Items]

Reserve margin

20.70%

17.40%

0.90%

PNM | Maximum

Public Utilities, General Disclosures [Line Items]

Reserve margin

12.50%

9.80%

3.40%

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

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

900

900

PNM | Deferred COVID-19 Costs | COVID-19

Public Utilities, General Disclosures [Line Items]

Regulatory assets

6,800

$ 6,900

$ 6,900

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

Number of megawatts in battery storage facilities (in megawatts) | MW

40

100

PNM | Replacement Resource Portfolio One | Subsequent event

Public Utilities, General Disclosures [Line Items]

Solar generation capacity (in megawatts) | MW

150

Number of megawatts in battery storage facilities (in megawatts) | MW

40

PNM | Replacement Resource Portfolio Two

Public Utilities, General Disclosures [Line Items]

Solar generation capacity (in megawatts) | MW

100

Number of megawatts in battery storage facilities (in megawatts) | MW

100

30

PNM | Replacement Resource Portfolio Two | Subsequent event

Public Utilities, General Disclosures [Line Items]

Number of megawatts in battery storage facilities (in megawatts) | MW

100

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 | Replacement Resource Portfolio Three | Subsequent event

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 (in megawatts) | MW

85

85

PNM | Portfolio Two

Public Utilities, General Disclosures [Line Items]

Number of megawatts available in purchase power agreement (in megawatts) | MW

150

150

PNM | Portfolio Three

Public Utilities, General Disclosures [Line Items]

Number of megawatts available in purchase power agreement (in megawatts) | MW

40

40

San Juan Generating Station

Public Utilities, General Disclosures [Line Items]

Severance costs

8,900

Estimated costs of replacement resources

$ 8,100

San Juan Generating Station | Other deferred credits

Public Utilities, General Disclosures [Line Items]

Restructuring reserve

36,800

$ 36,900

$ 36,900

San Juan Generating Station | Employee Severance

Public Utilities, General Disclosures [Line Items]

Restructuring reserve

27,700

$ 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

35,900

$ 36,000

$ 36,000

San Juan Generating Station | PNM | Employee Severance

Public Utilities, General Disclosures [Line Items]

Restructuring reserve

$ 26,800

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

Regulatory and Rate Matters - C

Regulatory and Rate Matters - Community Solar (Details)	Mar. 31, 2022MW
Community Solar Act
Public Utilities, General Disclosures [Line Items]
Solar generation capacity (in megawatts)	200

Regulatory and Rate Matters -_2

Regulatory and Rate Matters - San Juan Generating Station Unit 1 Outage (Details) - San Juan Generating Station $ in Millions	Mar. 31, 2022USD ($)
San Juan Generating Station Owners | Insurance Deductible
Public Utilities, Commitments And Contingencies [Line Items]
Estimate of possible loss	$ 2
PNM | Insurance Deductible
Public Utilities, Commitments And Contingencies [Line Items]
Estimate of possible loss	$ 1
PNM | San Juan Generating Station Unit 1
Public Utilities, Commitments And Contingencies [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners	50.00%

Regulatory and Rate Matters -_3

Regulatory and Rate Matters - Schedule of Transmission Cost of Service Rates (Details) - PUCT - TNMP - USD ($) $ in Millions	Mar. 25, 2022	Sep. 20, 2021	Mar. 12, 2021
Public Utilities, General Disclosures [Line Items]
Approved Increase in Rate Base	$ 95.6	$ 41.2	$ 112.6
Annual Increase in Revenue	$ 14.2	$ 6.3	$ 14.1

Regulatory and Rate Matters - F

Regulatory and Rate Matters - Formula Transmission Rates (Details)	3 Months Ended
	Mar. 31, 2022
Regulated Operations [Abstract]
Return on equity	10.00%

Regulatory and Rate Matters - U

Regulatory and Rate Matters - Unexecuted Transmission Service Agreements (TSAs) with Leeward Renewable Energy (Details)	Mar. 12, 2021MW
Public Service Company of New Mexico
Public Utilities, General Disclosures [Line Items]
Solar generation capacity related to unexecuted transmission service agreement (in megawatts)	145

Regulatory and Rate Matters - T

Regulatory and Rate Matters - TNMP Narrative (Details) - TNMP	Apr. 05, 2022USD ($)	Jul. 01, 2021USD ($)	Apr. 05, 2021USD ($)	Dec. 31, 2018USD ($)	Mar. 31, 2022USD ($)	Dec. 31, 2021USD ($)	May 27, 2021USD ($)	Mar. 01, 2021USD ($)	Dec. 31, 2020USD ($)	Mar. 30, 2020MWh
Public Utilities, Commitments And Contingencies [Line Items]
Requested increase in annual distribution revenue			$ 14,000,000
Increase in revenue base rate			$ 104,500,000
Collection of increase in annual distribution revenues		$ 13,500,000
Energy efficiency cost recovery, requested change amount							$ 7,200,000	$ 5,900,000
Energy efficiency cost recovery, requested bonus							$ 2,300,000	$ 1,000,000
Rider charge from electricity relief program (per MWh) | MWh										0.33
Subsequent event
Public Utilities, Commitments And Contingencies [Line Items]
Requested increase in annual distribution revenue	$ 9,700,000
Increase in revenue base rate	$ 100,700,000
PUCT
Public Utilities, Commitments And Contingencies [Line Items]
Public utilities, costs of deployment				$ 9,000,000
COVID-19
Public Utilities, Commitments And Contingencies [Line Items]
Regulatory liability					$ 200,000	$ 0			$ 100,000

Lease Commitments - Narrative (

Lease Commitments - Narrative (Details) $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2022USD ($)	Mar. 31, 2022USD ($)	Mar. 31, 2021USD ($)	Dec. 31, 2021USD ($)	Apr. 02, 2021lease	Jan. 15, 2016lease	Jan. 15, 2015lease
Operating Leased Assets [Line Items]
Operating lease, payments to lessor upon occurrence of certain events		$ 145
Unamortized cost, right-of-way lease payments		52.6		$ 53.4
Operating lease, right-of-use asset, amortization expense		1	$ 0.9
Lessee, operating lease, unguaranteed residual value		25.3
PNM
Operating Leased Assets [Line Items]
Number of leases under which lease term was extended | lease					5
Lessee, operating lease, unguaranteed residual value		11.6
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
PNM | Navajo Nation | Subsequent event
Operating Leased Assets [Line Items]
Right-of-way lease payments	$ 7.8
TNMP
Operating Leased Assets [Line Items]
Lessee, operating lease, unguaranteed residual value		13.7
Equipment
Operating Leased Assets [Line Items]
Operating lease, residual value of leased asset		2.3
Equipment | PNM
Operating Leased Assets [Line Items]
Operating lease, residual value of leased asset		0.9
Equipment | TNMP
Operating Leased Assets [Line Items]
Operating lease, residual value of leased asset		$ 1.4

Lease Commitments - Operating L

Lease Commitments - Operating Lease Balance Sheet Information (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Operating leases:
Operating lease assets, net of amortization	$ 74,126	$ 79,511
Current portion of operating lease liabilities	27,722	27,218
Long-term portion of operating lease liabilities	47,369	55,993
PNM
Operating leases:
Operating lease assets, net of amortization	69,022	73,903
Current portion of operating lease liabilities	25,826	25,278
Long-term portion of operating lease liabilities	44,377	52,552
TNMP
Operating leases:
Operating lease assets, net of amortization	4,782	5,264
Current portion of operating lease liabilities	1,853	1,882
Long-term portion of operating lease liabilities	$ 2,713	$ 3,155

Lease Commitments - Finance Lea

Lease Commitments - Finance Lease Balance Sheet Information (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Financing leases:
Non-utility property	$ 32,188	$ 31,695
Accumulated depreciation	(11,171)	(9,660)
Non-utility property, net	21,017	22,035
Other current liabilities	5,881	5,813
Other deferred credits	15,008	16,075
PNM
Financing leases:
Non-utility property	15,613	15,171
Accumulated depreciation	(5,282)	(4,550)
Non-utility property, net	10,331	10,621
Other current liabilities	2,818	2,731
Other deferred credits	7,373	7,732
TNMP
Financing leases:
Non-utility property	16,232	16,181
Accumulated depreciation	(5,679)	(4,923)
Non-utility property, net	10,553	11,258
Other current liabilities	2,975	2,994
Other deferred credits	$ 7,586	$ 8,273

Lease Commitments - Schedule of

Lease Commitments - Schedule of Weighted Average Remaining Lease Terms and Discount Rates (Details)	Mar. 31, 2022
Weighted average remaining lease term (years):
Operating leases	6 years 7 days
Financing leases	4 years
Weighted average discount rate:
Operating leases	4.02%
Financing leases	2.66%
PNM
Weighted average remaining lease term (years):
Operating leases	6 years 2 months 23 days
Financing leases	4 years 1 month 6 days
Weighted average discount rate:
Operating leases	4.03%
Financing leases	2.62%
TNMP
Weighted average remaining lease term (years):
Operating leases	2 years 9 months
Financing leases	3 years 11 months 4 days
Weighted average discount rate:
Operating leases	4.00%
Financing leases	2.71%

Lease Commitments - Components

Lease Commitments - Components of Lease Expense (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Lease, Cost [Line Items]
Operating lease cost:	$ 7,237	$ 7,429
Amounts capitalized	(654)	(785)
Total operating lease expense	6,583	6,644
Financing lease cost:
Amortization of right-of-use assets	1,511	1,167
Interest on lease liabilities	141	139
Amounts capitalized	(1,213)	(993)
Total financing lease expense	439	313
Variable lease expense	106	63
Short-term lease expense	1,169	132
Total lease expense for the period	8,297	7,152
Cooling Towers
Financing lease cost:
Short-term lease expense	1,100	1,100
Increase reimbursements	1,100	1,100
PNM
Lease, Cost [Line Items]
Operating lease cost:	6,683	6,735
Amounts capitalized	(185)	(226)
Total operating lease expense	6,498	6,509
Financing lease cost:
Amortization of right-of-use assets	732	532
Interest on lease liabilities	68	62
Amounts capitalized	(497)	(368)
Total financing lease expense	303	226
Variable lease expense	106	63
Short-term lease expense	1,132	124
Total lease expense for the period	8,039	6,922
TNMP
Lease, Cost [Line Items]
Operating lease cost:	528	653
Amounts capitalized	(469)	(559)
Total operating lease expense	59	94
Financing lease cost:
Amortization of right-of-use assets	757	613
Interest on lease liabilities	73	76
Amounts capitalized	(717)	(625)
Total financing lease expense	113	64
Variable lease expense	0	0
Short-term lease expense	0	2
Total lease expense for the period	$ 172	$ 160

Lease Commitments - Schedule _2

Lease Commitments - Schedule of Supplemental Cash Flows Related to Leases (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$ 9,318	$ 9,401
Operating cash flows from financing leases	31	30
Finance cash flows from financing leases	386	278
Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	1,079	317
Financing leases	492	1,164
PNM
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	9,244	9,246
Operating cash flows from financing leases	22	21
Finance cash flows from financing leases	260	186
Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	1,079	0
Financing leases	441	758
TNMP
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	49	97
Operating cash flows from financing leases	8	8
Finance cash flows from financing leases	104	71
Non-cash information related to right-of-use assets obtained in exchange for lease obligations:
Operating leases	0	317
Financing leases	$ 51	$ 387

Lease Commitments - Schedule _3

Lease Commitments - Schedule of Future Expected Lease Payments (Details) $ in Thousands	Mar. 31, 2022USD ($)
Financing
Remainder of 2022	$ 4,797
2023	6,035
2024	4,838
2025	3,100
2026	1,892
Later years	1,414
Total minimum lease payments	22,076
Less: Imputed interest	1,187
Lease liabilities as of March 31, 2022	20,889
Operating
Remainder of 2022	18,630
2023	19,558
2024	8,958
2025	7,802
2026	7,042
Later years	22,315
Total minimum lease payments	84,305
Less: Imputed interest	9,214
Lease liabilities as of March 31, 2022	75,091
PNM
Financing
Remainder of 2022	2,293
2023	2,952
2024	2,267
2025	1,450
2026	1,048
Later years	801
Total minimum lease payments	10,811
Less: Imputed interest	620
Lease liabilities as of March 31, 2022	10,191
Operating
Remainder of 2022	16,918
2023	17,778
2024	7,953
2025	6,992
2026	6,928
Later years	22,132
Total minimum lease payments	78,701
Less: Imputed interest	8,498
Lease liabilities as of March 31, 2022	70,203
TNMP
Financing
Remainder of 2022	2,435
2023	3,028
2024	2,557
2025	1,648
2026	844
Later years	613
Total minimum lease payments	11,125
Less: Imputed interest	564
Lease liabilities as of March 31, 2022	10,561
Operating
Remainder of 2022	1,496
2023	1,546
2024	943
2025	770
2026	76
Later years	0
Total minimum lease payments	4,831
Less: Imputed interest	265
Lease liabilities as of March 31, 2022	$ 4,566

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended	12 Months Ended
	Dec. 31, 2021	Jun. 30, 2021	Mar. 31, 2022	Dec. 31, 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
Refund amount of AMT tax, CARES act		$ 5.2
Payment of payroll taxes, CARES Act	$ 3.5
Deferred federal, state and local, income taxes				$ 23.6
Effective tax rate			13.12%
PNM
Income Tax Contingency [Line Items]
Deferred federal, state and local, income taxes				14.4
Effective tax rate			14.50%
TNMP
Income Tax Contingency [Line Items]
Deferred federal, state and local, income taxes				$ 9.2
Effective tax rate			12.37%
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

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Related Party Transaction [Line Items]
Ownership	50.00%
Services billings: | PNMR to PNM
Related Party Transaction [Line Items]
Amount of related party transaction	$ 27,693	$ 26,225
Services billings: | PNMR to TNMP
Related Party Transaction [Line Items]
Amount of related party transaction	10,304	10,365
Services billings: | PNM to TNMP
Related Party Transaction [Line Items]
Amount of related party transaction	93	118
Services billings: | TNMP to PNMR
Related Party Transaction [Line Items]
Amount of related party transaction	35	12
Services billings: | PNMR to NMRD
Related Party Transaction [Line Items]
Amount of related party transaction	64	55
Renewable energy purchases: | PNM from NMRD
Related Party Transaction [Line Items]
Amount of related party transaction	2,621	2,585
Interconnection and facility study billings: | PNM from NMRD
Related Party Transaction [Line Items]
Amount of related party transaction	0	0
Interconnection and facility study billings: | PNM to PNMR
Related Party Transaction [Line Items]
Amount of related party transaction	0	0
Interconnection and facility study billings: | NMRD to PNM
Related Party Transaction [Line Items]
Amount of related party transaction	0	1,276
Interest billings: | PNMR to PNM
Related Party Transaction [Line Items]
Amount of related party transaction	7	0
Interest billings: | PNMR to TNMP
Related Party Transaction [Line Items]
Amount of related party transaction	45	0
Interest billings: | PNM to PNMR
Related Party Transaction [Line Items]
Amount of related party transaction	23	36
Income tax sharing payments: | PNMR to PNM
Related Party Transaction [Line Items]
Amount of related party transaction	0	0
Income tax sharing payments: | TNMP to PNMR
Related Party Transaction [Line Items]
Amount of related party transaction	$ 0	$ 0

Equity Method Investment (Detai

Equity Method Investment (Details) $ in Thousands	1 Months Ended	3 Months Ended
	Feb. 28, 2021USD ($)	Mar. 31, 2022USD ($)MW	Mar. 31, 2021USD ($)
Business Acquisition [Line Items]
Ownership		50.00%
Distributions from NMRD		$ 0	$ 572
NMRD
Business Acquisition [Line Items]
Renewable energy capacity in operating (in mw) | MW		135.1
PNMR Development | NMRD
Business Acquisition [Line Items]
Ownership		50.00%
Distributions from NMRD	$ 3,000
Earnings from equity method investments, net of dividends or distributions	$ 2,400
Proceeds from equity method investment, distribution, return of capital			$ 600
AEP OnSite Partners | NMRD
Business Acquisition [Line Items]
Ownership		50.00%

Equity Method Investment - Summ

Equity Method Investment - Summarized Financial Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Results of Operations
Operating revenues	$ 444,118	$ 364,707
Financial Position
Net property, plant, and equipment	313,901		$ 248,856
Assets	8,727,686	7,943,309	8,666,885
Total PNM common stockholder’s equity	2,115,532		2,167,524
NMRD
Results of Operations
Operating revenues	2,796	2,750
Operating expenses	2,404	2,522
Net Earnings Attributable to PNM	392	$ 228
Financial Position
Current assets	5,827		10,729
Net property, plant, and equipment	164,733		166,495
Non-current assets	9,653		2,289
Assets	180,213		179,513
Current liabilities	1,148		824
Non-current liabilities	377		373
Total PNM common stockholder’s equity	$ 178,688		$ 178,316

Merger (Details)

Merger (Details) - Merger Agreement - Forecast - USD ($) $ / shares in Units, $ in Millions	Apr. 20, 2023	Dec. 31, 2022
Business Acquisition [Line Items]
Business combination, cash right per common share (in dollars per share)		$ 50.30
Termination fees	$ 130
Out-of-pocket fees and expenses reimbursement	10
Avangrid
Business Acquisition [Line Items]
Termination fees	$ 184